Integrated power production and storage systems

ABSTRACT

A power plant is configured to output power to a grid power system and comprises a hydrogen generation system configured to produce hydrogen, a gas turbine combined cycle power plant comprising a gas turbine engine configured to combust hydrogen from the hydrogen generation system to generate a gas stream that can be used to rotate a turbine shaft and a heat recovery steam generator (HRSG) configured to generate steam with the gas stream of the gas turbine engine to rotate a steam turbine, a storage system configured to store hydrogen produced by the hydrogen generation system, and a controller configured to operate the hydrogen generation system with electricity from the grid power system when the grid power system has excess energy and balance active and reactive loads on the grid power system using at least one of the hydrogen generation system and the gas turbine combined cycle power plant.

CROSS-REFERENCE TO RELATED APPLICATION

This patent application claims the benefit of U.S. Provisional PatentApplication Nos. 63/073,282, filed Sep. 1, 2020; 63/174,275, filed Apr.13, 2021; and 63/233,383 filed Aug. 16, 2021, each of which areincorporated by reference herein in their entirety

TECHNICAL FIELD

This document pertains generally, but not by way of limitation, tocombined-cycle power plants used to generate electricity. Morespecifically, but not by way of limitation, the present applicationrelates to production, use and storage of hydrogen and oxygen incombined-cycle power plants that can be integrated into manufacturing orproduction facilities.

BACKGROUND

The grid is a mechanism to balance aggregate energy demand of consumerswith aggregate energy supply of power producers, including renewableenergy sources and traditional power plants, such as those that burnfossil fuels.

Renewable energy sources can comprise sources of energy that do notinclude combustion or release of CO2. Typical renewable energy sourcesinclude hydroelectric, solar and wind. Solar and wind, particularly, areintermittent and unpredictable.

Power plants can comprise a means to generate power on demand usingfuels, such as fossil fuels or hydrogen derived from various sources.Fossil fuels can comprise coal, natural gas or fuel oil. Typical powerplants comprise a gas turbine and an electrical generator, andfrequently include a steam turbine in a combined-cycle configuration.The gas turbine and steam turbine can create electric power frommechanical energy converted from combustion of fuel and associated steamgeneration processes.

Consumers of electricity comprise any user of electrical power.Consumers can be a residential consumers, commercial consumers orindustrial consumers. Consumers can use energy in different ways,thereby placing widely differing demands on the grid.

Apparent Power, Real Power and Reactive Power

Electric circuits are comprised of different types of power producers,or “generators,” and power consumers or “loads.” Generators producepower that flows to the loads, and is subsequently returned to thegenerator to complete the circuit. Active Loads are purely resistiveloads that generate no magnetic field and convert electrical powerpurely to other forms of energy, with examples being heaters andincandescent light bulbs. Reactive Loads are those that generate amagnetic field in order to convert electrical power to other forms ofenergy, such as rotating mechanical power as in induction motors orsound as in speakers. When Reactive Loads are present in an electriccircuit, it appears that more power is supplied by the generator to theloads (“Apparent Power”) than the power consumed by the loads (“RealPower”) and there exists a difference in the alignment between thevoltage and current, known as phase alignment, due to the requirement togenerate the magnetic fields. In an AC Circuit, Apparent Power (S) isthe product of the voltage (V) and the current (I) given by the equation(S=VI). The amount of phase alignment between voltage and current isrepresented by the angle (Φ) and has a range of negative (−) 90 degreesto positive (+) 90 degrees. A phase angle Φ=zero represents voltage andcurrent are in full phase alignment and S=VI represents not only theApparent Power, but also the Real Power (P) and S=P=VI. This correspondsto a circuit containing purely Active Loads and containing no ReactiveLoads. In circuits where Reactive Loads are present, voltage and currentare out of phase due to the requirement to create the magnetic fieldsand it appears that more power is supplied by the generator than isconsumed by the loads and Φ represents the amount of alignment, or phaseangle, between voltage and current, and Real Power is given by theequation P=VI cos(Φ). The difference between Apparent Power and RealPower is given by the relationship S=(P{circumflex over( )}2+Q{circumflex over ( )}2){circumflex over ( )}(1/2) with Q beingdefined as “Reactive Power.” Reactive Power is then the differencebetween the Apparent Power and Real Power developed in a circuit, withReactive Power given by the relationship Q=VI sin(Φ) and measured in aunit known as Volt-Amp-Reactive or VAR. Reactive Power can be generatedwithin a generator by raising or lowering the voltage that generates themagnetic field (the “Excitation Voltage”) or by managing the amount ofreactive loads within a circuit such as dispatching them on or off tomanage the overall system VAR flow. Failure to manage balance flows ofboth Active and Reactive Power can result in fluctuations in bothvoltage and frequency within a power system leading to damage toelectrical equipment.

An Inverter is an electrical device that converts direct currentelectrical power to alternating current electrical power.

A Rectifier is an electrical device that converts alternating currentelectrical power to direct current electrical power.

As mentioned, various factors can have a substantial impact on gridstability. Specifically, (1) when a large industrial consumer initiates(or discontinues) use of large quantities of power; or (2) when thereare large variations in the demand for power by residential and/orcommercial consumers during a) peak periods, such as morning andevening, versus off-peak periods, such as over-night and mid-day and b)seasonal variations in demand such as cooling load in summer, heatingload in winter and relatively low demand for either in spring and fall;or (3) when the types of loads change on a system, such as large amountsof active loads being initiated or discontinued such as lighting withthe rise and fall of daylight, and electric heaters that are initiatedor discontinued as occurs with changing temperatures within the winterseason; or (4) when the types of generation available changes, such aswind, solar, nuclear or fossil fuels with changing weather patterns atboth a local, regional and national scale, either (a) in the short termin the case of changing weather systems or (b) on a seasonal basis asoccurs with the transition from spring to summer to autumn to winter; or5) how the consumers use the power can influence Active and Reactivepower availability in addition to system voltage and frequency. Forexample, use of large inductive motors by one consumer can result in theneed for large quantities of reactive power, which, in effect, canreduce the availability of real power to be used by other consumers orcan impact the voltage and frequency on the grid that needs to beadjusted to avoid damage to electrical components and devices. Suchdemands need to be balanced with all of the aforementioned changes toApparent Power, Real Power and Reactive Power (collectively, along withother such similar changes in the grid, referred to hereafter as “Activeand Reactive Power Changes”).

According to the aforementioned Active and Reactive Power Changes, thegrid must react to maintain balance between supply and demand of ActivePower, Reactive Power, system voltage and frequency. The way the gridcurrently reacts is to cause at least some suppliers of power from bothpower plants and renewable sources to increase or reduce their output ofReal Power in terms of the amount of watts provided to maintain balanceand to change the nature of their operation to balance Reactive Power byproviding or consuming the same in terms of the VARS consumed orprovided. These various supplies and demands of Active Power, ReactivePower, system voltage and frequency are typically operating in isolationfrom one another with only the grid controller managing Active andReactive Power Changes. Such external management can be complex and canrequire many instances of power producers starting and stopping andvarying output levels, which introduces inefficiencies into the overallsystem.

OVERVIEW

The present inventors have recognized, among other things, that problemsto be solved in power plants can include inefficient production, usageand storage of electrical power, particularly as consumers change powerdemand and power producers attempt to react to the changes in demand.

The present inventors have recognized that, ideally, the grid desires toconsume as much renewable energy as possible because such energy isperceived to be supplied at lower cost with reduced environmentalimpacts relative to traditional power plants utilizing fossil fuels.However, availability of such renewable energy is intermittent andunpredictable. The sun is only available for part of the day, and windis unpredictable, and the availability of both forms of energy varieswith the seasons. Therefore, as the supply of renewable energy or demandfluctuates, the output of power plants and reactive power balance isrequested to fluctuate. Additionally, as the demand and reactive powerbalance fluctuates, in some instances measures can be taken to reducesupply from the renewable sources, such as to reduce wind turbine bladepitch. However, this is sub-optimal, as it represents a lost opportunityto utilize power with lower cost and reduced environmental impacts. Insome areas where the supply of solar energy is plentiful, power plantscan be requested to be “off” (generate no power) during the day and “on”during the evening.

However, a power plant represents a complex system that has substantialphysical and thermal mass. These systems often require substantialperiods of time to start up or shut down in order to avoid damage thatcan result from severe thermal gradients associated with a rapidtransition in power output. Further, complex systems are typicallydesigned to provide optimum performance at a particular design point,and operation at other points is often sub-optimal. For example a gasturbine is often designed to provide optimum efficiency and emissionsoutputs at a specific base power output, and operation at other poweroutputs is less efficient and/or results in increased unfavorableemissions. Therefore, it is desirable that gas turbine power plants: (1)operate as close to their base output design point; and (2) avoid thesevere thermal gradients associated with rapid output transition.

In response to system Active and Reactive Power Changes, and a desire toobtain maximum consumption of renewable energy, the grid can ordinarilycommand a power plant to increase or reduce its power output to matchthe reduced demand, often at rates of change that are detrimental to thepower plant.

The present subject matter can help provide solutions to these problemsand other problems, such as by using novel thermal and electricalintegration of various equipment, short term and long term storagesystems and strategies, and novel operational concepts and controls. Thevarious systems of the present disclosure can 1) stabilize a gas turbineoperating profile, 2) provide consistent Active and Reactive Power overa range of scenarios within a power system grid, 3) provide rapidresponse to the changing demand for Active and Reactive Power 4) providevoltage and frequency support to the grid, 4) maximize the utilizationof renewable energy available, and 5) reduce the carbon dioxideemissions of the gas turbine power plant in either simple cycle orcombined cycle configurations during fluctuations in renewable energysupply and consumer demand.

For example, under normal circumstances, electrolyzers take time tostart operating at large volumes of power consumption due to the need toheat the water within the units. However, through novel integration ofthe combustion turbine power plant and electrolyzers, the water can bemaintained at operating temperature such that in response to a largeindustrial consumer ceasing its demand for power, the grid can commandthe electrolyzer to immediately begin to consume electricity to convertwater into hydrogen and oxygen gas. For example, the feed water to anelectrolyzer can first be conditioned by passing through, or being bledoff of, a heat recovery steam generator (HRSG) that captures heat energyfrom a gas turbine to create steam to drive a steam turbine. If theelectrolyzer capacity is equal to or greater than the amount of powerthat the consumer had been using, initiation of conversion of water canmaintain grid balance without any need to alter the operating profile ofthe gas turbine.

At the same time that the electrolyzer begins to convert water (H₂O)into H2 (H₂) and O2 (O₂), the gas turbine can alter its operation suchthat it begins to consume H2 and likewise decrease its consumption offossil fuel (i.e., natural gas or fuel oil). In this manner, the gridcan maintain balance while maximizing its use of renewable energy,avoiding severe transitions in gas turbine loading, and reducingconsumption and the corresponding purchase and environmental costsassociated with combustion of fossil fuel. H2 can be blended with otherfuels, or can be the only fuel consumed by the gas turbine. In anyevent, consumption of H2 represents an improvement in gas turbineemissions, since the only combustion product of H2 is water vapor.

Further, the control system can utilize intelligence to alter operationof the gas turbine. For example, if the control system has reason toexpect that the consumer demand will not increase for some time, it canelect to shut down the gas turbine at a transition rate that avoidsdevelopment of damaging thermal gradients, and in a manner that is mostefficient and reduces environmental emissions. As the output of the gasturbine transitions, so can the consumption of the electrolyzer, therebyproviding an inherently balanced transition.

Additionally, through the use of inverters and rectifiers, theelectrolyzer can be used to balance the reactive power on the grid.

Further, the electrolyzer can be coupled with H2 storage, which canenhance even further the flexibility provided by the system. Withsufficient H2 storage, during periods of peak supply, (such as whensupply can dramatically outpace demand and the grid would otherwiserequest the shutdown of the gas turbine or curtail the production ofrenewable sources), the system can allow the gas turbine to operate atits optimum design point and avoid such curtailment. In such asituation, the surplus power (i.e., difference between supply anddemand) can be used to power the electrolyzer to generate and store H2gas.

Ideally, during such periods, power generation capacity of H2 output ofthe electrolyzer will exceed the power generation of the gas turbine,such that the gas turbine will be operated at its design point on 100%H2 gas and hydrogen can be stored for future use. In such a scenario,the gas turbine will be operating at its most efficient point withemissions of only water vapor.

The system can utilize differing amounts of H2 storage depending uponthe needs. As explained above, the grid balancing benefit and reductionof emissions while avoiding severe thermal gradients can be accomplishedwith minimal storage. However, with the addition of storage thesebenefits can be enhanced by allowing maximum use of renewable energywhile continuing operation of the gas turbine at its optimum designpoint (or with sufficiently long transition points to minimize damagingthermal gradients).

For those instances where it is desired to optimize storage, atransportation pipeline can offer substantial storage. For example, itis known that a gas turbine operating at 500 Megawatts power output willconsume approximately 27 tons of H2 per hour of operation when operatingat 100% H2 content. Typical fuel pressures for gas turbine operation areapproximately less than 800 pounds per square inch (psi). A 24 inchdiameter pipe with minimum wall thickness of 0.834 inches has sufficientstrength to withstand 3,000 psig of H2 gas. Each (1) mile length of suchpipe can contain 4.6 tons of H2 gas when cycled between 3,000 psig and800 psig. That is, each 6 miles of pipe can store 27.6 tons of H2 whichcan provide approximately one hour of operation of a gas turbine at 500MW.

If a gas turbine is located sufficient distance from the H2 source, thetransportation pipeline itself can provide sufficient storage.Additionally, if the gas turbine and H2 source are co-located, apipeline, or multiple pipelines, each with one end capped or connectedtogether to form a closed system can be run from the site to somedistance away from the site forming an artificial underground storagevessel. However, if additional, onsite storage is necessary or desired,the arrangement of pipes as shown herein can provide an improved storagearrangement. The arrangement of pipes described herein can includealternating arrays of pipe, in an inverted pyramid, arrangedunderground, with construction fill therebetween. In practice, theconstruction fill is arranged to provide the inverted pyramid geometry,and the pipes are laid upon each other. Because of hoop strength and theinverted pyramid geometry, no internal framework or structure isnecessary.

In an example, a power plant can be configured to output power to a gridpower system and can comprise a hydrogen generation system configured toproduce hydrogen, a gas turbine combined cycle power plant comprising agas turbine engine configured to combust hydrogen from the hydrogengeneration system to generate a gas stream that can be used to rotate aturbine shaft and a heat recovery steam generator (HRSG) configured togenerate steam with the gas stream of the gas turbine engine to rotate asteam turbine, a storage system configured to store hydrogen produced bythe hydrogen generation system, and a controller configured to operatethe hydrogen generation system with electricity from the grid powersystem when the grid power system has excess energy and balance activeand reactive loads on the grid power system using at least one of thehydrogen generation system and the gas turbine combined cycle powerplant.

In another example, a power plant can be configured to output power to agrid power system and can comprise an electrolyzer configured to producehydrogen and oxygen, a gas turbine combined cycle power plant comprisinga gas turbine engine configured to combust hydrogen from the hydrogengeneration system to generate a gas stream that can be used to rotate aturbine shaft and a heat recovery steam generator (HRSG) configured togenerate steam with the gas stream of the gas turbine engine to rotate asteam turbine, a storage system configured to store hydrogen produced bythe hydrogen generation system, and a nozzle configured to introduceoxygen from the electrolyzer into the HRSG of the gas turbine combinedcycle power plant.

In an additional example, a method of combusting fuel using a thermalnozzle can comprise (A) providing oxidant having an oxygen concentrationof at least 30 volume percent at an initial velocity less than 300 fpswithin an oxidant supply duct communicating with a combustion zone, (B)providing fuel separately from oxidant into the oxidant supply duct at ahigh velocity of greater than 200 feet per second and greater than saidoxidant initial velocity entraining oxidant into the high velocity fuel,combusting up to about 20 percent of the oxygen of the oxidant providedinto the oxidant supply duct with the fuel to produce heat andcombustion reaction products in a combustion reaction, and furtherentraining combustion reaction products and oxidant into the combustionreaction, (C) mixing combustion reaction products with remaining oxygenof the oxidant within the oxidant supply duct and raising thetemperature of remaining oxidant within the oxidant supply duct, and (D)passing heated oxidant out from the oxidant supply duct into thecombustion zone at an exit velocity which exceeds the initial velocityby at least 300 feet per second, wherein the heated oxidant passes outof the oxidant supply duct from a plurality of orifices arranged indifferent orientations.

In an example, a power plant configured to output power to a grid powersystem can comprise an electrolyzer configured to produce hydrogen andoxygen, a power converter electrically connecting the electrolyzer tothe grid power system, a gas turbine combined cycle power plantcomprising a gas turbine engine configured to combust hydrogen from thehydrogen generation system to generate a gas stream that can be used torotate a turbine shaft and a heat recovery steam generator (HRSG)configured to generate steam with the gas stream of the gas turbineengine to rotate a steam turbine, a storage system configured to storehydrogen produced by the hydrogen generation system, and a controllerconfigured to balance active and reactive loads on the grid power systemusing at least one of the power converter, the hydrogen generationsystem and the gas turbine combined cycle power plant.

In an example, a method of operating an integrated power plant connectedto a grid power system can comprise operating a gas turbine engine todrive a first electric generator to provide power to the grid powersystem, the gas turbine engine operable on at least one of hydrogen andnatural gas, operating an electrolyzer to generate hydrogen and oxygenwith electricity from the grid power system, storing hydrogen producedby the electrolyzer in a storage system, and coordinating operation ofthe gas turbine engine and electrolyzer to power demand of the gridpower system.

This overview is intended to provide an overview of subject matter ofthe present patent application. It is not intended to provide anexclusive or exhaustive explanation of the invention. The detaileddescription is included to provide further information about the presentpatent application.

BRIEF DESCRIPTION OF THE DRAWINGS

FIGS. 1A and 1B are a schematic diagram illustrating an integrated powerproduction system comprising a combined cycle gas turbine power plant(GTCC), a hydrogen production system, a hydrogen storage system, and acontroller.

FIG. 2 is a schematic diagram illustrating an example master controlsystem for the sub-systems of FIGS. 3-10 suitable for use in anintegrated power production system of FIGS. 1A and 1B.

FIG. 3 is a schematic diagram illustrating an example combined cyclepower plant having a an electrolyzer connected to a hydrogen receivingtank and power conversion equipment.

FIG. 4 is a schematic diagram illustrating a heat recovery steamgenerator connected to an electrolyzer, which is also connected to abattery and a renewable energy source.

FIG. 5 is a schematic diagram illustrating a cooling loop for anelectrolyzer bank.

FIG. 6 is a line diagram illustrating a heat recovery steam generatorconnected to an electrolyzer and a hydrogen surge system.

FIG. 7 is a schematic diagram illustrating of a hydrogen storage system.

FIG. 8 is a schematic diagram illustrating a poly-generation facilitycomprising a combined cycle power plant, renewable energy producers,hydrogen and oxygen storage systems and, an electrolyzer connected to anindustrial power consumer or plant.

FIG. 9 is a schematic diagram illustrating a nozzle for generating hotoxygen to inject into a heat recovery steam generator.

FIG. 10 is a schematic diagram illustrating a hybrid power converterconnecting the grid to an electrolyzer bank, a battery bank andrenewable energy sources.

FIG. 11 is a schematic diagram illustrating a vertically disposed pipingsystem suitable for use as a hydrogen storage system.

FIG. 12 is a schematic diagram illustrating a plurality of verticallydisposed piping systems.

FIGS. 13A and 13B are schematic diagrams illustrating perspective andend views of a plurality of vertically disposed piping systems includingpipes with directional change.

FIGS. 14A and 14B are schematic diagrams illustrating side and top viewsof a plurality of vertically disposed piping systems including pipesdisposed in a radial arrangement.

FIG. 15 is a schematic diagram illustrating a side view of a pluralityof horizontally disposed piping systems arranged in a plurality oflevels.

FIGS. 16A-16F are schematic diagrams illustrating various arrangementsof layering of piping systems of the present disclosure.

FIGS. 17-17B are schematic diagrams illustrating top and side views ofan overhead support structure for fabricating and installing pipingsystems.

FIGS. 18-18B are schematic diagrams illustrating top and side views ofan overhead welding gantry system for fabricating and installing pipingsystems.

FIGS. 19-19B are schematic diagrams illustrating top and side views ofthe overhead welding gantry system of FIGS. 18-18B with further sectionsof pipe assembled.

FIGS. 20-20B are schematic diagrams illustrating an assembled pipevessel being lowered into a trench.

FIGS. 21-21B are schematic diagrams illustrating a second pipe vesselbeing assembled.

FIGS. 22-22B are schematic diagrams illustrating the second pipe vessellowered into the trench and a third pipe vessel being assembled.

FIGS. 23A-23C are schematic diagrams illustrating a plurality ofelongate, horizontal piping systems installed in a plurality of layerswith and without an access gallery.

FIG. 24 is a schematic diagram illustrating a plurality of verticallydisposed piping systems connected to a grid network including consumers.

FIG. 25 is a schematic diagram illustrating a plurality of verticallydisposed piping systems and an underground storage cavern connected to agrid network including consumers.

FIG. 26 is a schematic diagram illustrating a plurality of verticallydisposed piping system banks and an underground storage cavern connectedto a grid network including consumers.

FIG. 27 is a schematic diagram illustrating a plurality of verticallydisposed piping system banks and an underground storage cavern connectedto each other and a grid network including consumers.

FIG. 28 is a schematic diagram illustrating an underground storagecavern connected to a grid network without piping systems.

FIG. 29 is a schematic diagram illustrating components of controllersfor operating the integrated power production system of FIGS. 1A and 1B.

In the drawings, which are not necessarily drawn to scale, like numeralsmay describe similar components in different views. Like numerals havingdifferent letter suffixes may represent different instances of similarcomponents. The drawings illustrate generally, by way of example, butnot by way of limitation, various embodiments discussed in the presentdocument.

DETAILED DESCRIPTION

FIGS. 1A and 1B are a schematic diagram illustrating integrated powerproduction system 100 that provides many advantages over standard andprior art systems. System 100 can include combined cycle gas turbinepower plant (GTCC) 104, hydrogen production system 106, and controller108.

Control signals between various components and systems are designatedvia dash/dot lines, electrical connections through which electricity canflow are designated via dashed lines, and process lines, through whichgases or fluids can flow, are designated via solid lines.

In examples, hydrogen production system 106 can comprise an electrolyzerthat also produces oxygen. Power production system 100 can also includeeither or both of hydrogen storage system 110 and oxygen storage system112.

GTCC 104 can comprise gas turbine 114, heat recovery steam generator116, and steam turbine 118.

Controller 108 can be connected to hydrogen production system 106 viacontrollers 120 and 122. Controller 108 can be connected to GTCC 104 viacontrollers 124 and 126.

Grid 128 provides electrical connection between various supplies ofelectricity, such as renewable wind electricity sources 130, renewablephotovoltaic solar electricity sources 132 or combined cycle gas turbinepower plant 104, and consumers 152 of electricity. Example consumers 152include residential homes, commercial buildings, and industrialfacilities. Different consumers 152 can utilize varying levels of activeand reactive power.

Although only one consumer 152, one renewable wind electricity source130, one renewable photovoltaic solar electricity source 132, one GTCC104, one hydrogen production system 106, one hydrogen storage system 110and one oxygen storage system 112 are shown in FIGS. 1A and 1B, powerproduction system 100 can include multiple instances of each, either atthe same geographic locations or dispersed over a large geographicregion.

Master controller 108, among other things, provides command signals tothe various supplies of electricity, including wind electricity sources130, solar electricity sources 132, and gas turbine 104, to ensure thatthe total supply and demand for electricity remains balanced. Mastercontroller 108, in conjunction with electrolyzer production and VAR setpoint controllers 122, 120, respectively, and GTCC output and VARsetpoint controllers 124, 126, respectively, can ensure balance betweensupply and demand of active power, reactive power, system voltage andfrequency. Master controller 108 can also regulate when hydrogen isproduced, or consumed, and when power is dispatched by using the storedhydrogen or producing H2 for storage. As discussed with reference toFIGS. 4 and 10, for example, power production system 100 canadditionally include various battery storage systems for short termstorage of power and reactive load regulation, as described herein. Asdiscussed with reference to FIG. 8, for example, integrated powerproduction system 100 can additionally be integrated with industrialplants that consume power from grid 128 and that can receive variousinputs from system 100.

Decisions of master controller 108 can be made based on marketconditions, renewable power availability, grid electricity costs, andother factors. Thus, master controller 108 can manage power productionfrom renewable wind electricity sources 130, renewable photovoltaicsolar electricity sources 132 and combined cycle gas turbine power plant104 based on demand on grid 128, weather conditions and other factors,while also managing hydrogen production of hydrogen production system106 using, for example, consumption of hydrogen and oxygen in GTCC 104and industrial facility 350 (FIG. 8) and long term and short termstorage of energy in the form of hydrogen and oxygen storage in hydrogenstorage system 110 and oxygen storage system 112, respectively, andpower in various batteries.

Electricity from grid 128 can be first provided to transformer 133 totransform the voltage of grid 128 to a selected voltage that isoptimized for operation of power converter 134 to convert AC power to DCpower. In examples, converter 134 can be a rectifier and can bereceptive of alternating current (AC) from grid 128, and productive ofdirect current (DC) as can be optimal for operation of electrolyzers ofhydrogen production system 106. Converter 134 can additionally be ahybrid converter as described herein. GTCC 104, steam turbine 118, windelectricity sources 130 and solar electricity sources 132 can beprovided with transformers 135A-135D, respectively, to transform voltageof generated power to a voltage compatible with grid 128.

Hydrogen production system 106 can be connected to hydrogen purificationsystem 136, which can use hydrogen compressor 138 to provide hydrogen tohydrogen storage system 110, and oxygen purification system 140, whichcan provide oxygen to oxygen storage system 112. Hydrogen purificationsystem 136 can comprise a palladium membrane hydrogen purifier, a densethin-metal membrane purifier, a pressure swing adsorption system, acatalytic recombination or deoxygenation purifier, or an electrochemicalpurifier, as well as others. Oxygen purification system 140 can utilizea cryogenic distillation process or a vacuum swing adsorption process.Valve 142 can be used to control flow of stored hydrogen to gas turbine114. Valve 143 can be used to control flow of stored oxygen to HRSG 116.Valve 144 can be used to control flow of natural gas to gas turbine 114.Natural gas can be provided via natural gas source 146. Controller 108can control flow of hydrogen, oxygen and natural gas to GTCC 104 basedon factors described herein (e.g., availability of renewable energy) tooptimize total output (e.g., power and hydrogen) of system 100.

Combined cycle gas turbine power plant 104 includes gas turbine 114,heat recovery generator (HRSG) 116, and steam turbine 118. The functionsand operation of combined cycle gas turbine power plant 104 will beappreciated by one of skill in the art and many of the details of whichare not described here for brevity. Gas turbine 114 includes compressor148, combustor 150, and turbine 152. Compressor 148, turbine 150 andelectrical generator 154 can be physically connected via one or moreshafts, and turn together. Air is introduced to compressor 148,compressor 148 compresses the air, and fuel is introduced to thecompressed air in combustor 150. The fuel is ignited, and the combustionproducts have greatly increased temperature and pressure (and energy)relative to that of the compressed air. The high energy combustionproducts expand in turbine 152 driving compressor 148 and electricalgenerator 154.

After the high energy combustion products exit gas turbine 114, they arereferred to as exhaust gas, and are channeled through HRSG 116. HRSG 116can include one or more heat exchange assemblies that transfer heat fromthe exhaust gas to water. The water can be in the form of liquid wateror steam. HRSG 116 can have various stages to produce steam atparticular properties of temperature and pressure. Furthermore, as isdiscussed with reference to FIG. 3, heat from the steam can be used towarm electrolyzers of hydrogen production system 106 using, for example,heat exchanger 158 or heat exchanger 162. The steam is then directed tosteam turbine 118, which can be physically connected to generator 156via clutch 160. In examples, clutch 160 can be omitted. From steamturbine 118, the steam can flow into heat exchanger 162, such as acondenser in which the steam can be cooled. Heat from steam and waterfrom HRSG 116 can additionally be put into another system, as is shownin FIG. 8, for example. Generator 156 can, in some examples, be the samegenerator connected to gas turbine 114, or in other examples can be aseparate generator (as is shown in FIGS. 1A and 1B). The steam canexpand within steam turbine 118, and transfer torque to generator 156 tocreate electricity. Thereafter the steam can be condensed to liquidwater and return to HRSG 116 to be reheated to the particularproperties. As is customary, it will be appreciated that the water cancirculate between HRSG 116 and steam turbine 118 in a loop.

In examples, controller 108 is a master controller that is in signalcommunication with at least of one of electrolyzer VAR (volt-amperereactive) set point controller 120, electrolyzer production set pointcontroller 122, GTCC plant output controller 124, and GTCC plant VARsetpoint controller 126, each of which can be responsive to commandsignals provided by master controller 108 as described in further detailbelow.

Hydrogen production system 106 can produce hydrogen using a number ofdifferent processes. Thermochemical processes use heat and chemicalreactions to release hydrogen from organic materials, such as fossilfuels and biomass, or from materials like water. Water (H2O) can also besplit into hydrogen (H2) and oxygen (O2) using electrolysis or solarenergy. Microorganisms such as bacteria and algae can produce hydrogenthrough biological processes.

In examples, hydrogen production system 106 comprises an electrolyzer.The electrolyzer can be an electrical device that can operate to consumeelectricity to convert water into its constituent elements, hydrogen andoxygen. Generally, electrolyzers consume direct current electrical powerand utilize converter 134 to convert alternating current to directcurrent. Hydrogen can be stored in hydrogen storage system 110, whichcan comprise a tank, pipeline, salt cavern or other geologic repository,such as those discussed with reference to FIGS. 11-16F. The electrolyzerof hydrogen production system 106 is generally receptive of inputs ofwater and electricity, and productive of hydrogen gas and oxygen gas, aswould be appreciated by one of skill in the art.

Electricity can be provided via distribution grid 128. Grid 128 canobtain electricity from one or more of a variety of electrical sources,such as renewable wind electricity sources 130 and renewablephotovoltaic solar electricity sources 132. Grid 128 can also obtainelectricity from other sources, such as from hydroelectric sources,nuclear sources, one or both of generators 154 and 156 of gas turbine114 and steam turbine 118, respectively, of combined cycle gas turbineplant 104 or other gas turbine generators connected to grid 128.

The operation of the electrolyzer of hydrogen production system 106 canbe responsive to production set point controller 122. Production setpoint controller 122 can control the amount of direct current to provideto the electrolyzer. Provision of direct current and water to theelectrolyzer is directly related to the production of hydrogen gas andoxygen gas.

The operation of the electrolyzer of hydrogen production system 106 canalso be responsive to electrolyzer VAR set point controller 120. VAR setpoint controller 122 can control the amount of alternating current thatis converted to direct current to be provided to the electrolyzer.

Power inverters convert DC to AC power. Power inverters are gridconnected devices that allow for putting power into grid 128. Typicaluse of power inverters is unidirectional, and can be at photovoltaicsolar electricity sources 132 or fuel cells, for example.

In examples, converter 134 can include thyristor rectifier technologywith transistor electronics, that can convert 1, 2, or 3 phase AC powerto DC power. Such DC power output is typically unidirectional, notsmooth, and is commonly used for electroplating, DC processes, andelectrolyzer stacks.

In examples, converter 134 can include chopper rectifier technology,with a combination of silicon controlled rectifiers (SCRs) andinsulated-gate bipolar transistors (IGBTs), that convert 1, 2, or 3phase AC power to DC power. Such DC power output is typicallyunidirectional, not smooth and is commonly used for electroplating, DCprocesses, and electrolyzer stacks.

In examples, converter 134 can be a power conversion system (PCS) thatwill use IGBTs, and PWM (pulse wave modulation) to convert 1, 2 and 3phase AC power to DC as well as taking DC power from a source, such asan electrochemical battery or wind or solar generators, and convert theDC power to AC power. Such PCSs are bidirectional and both AC and DC are“clean”, close to pure waveforms, with no harmonics or “ripple”, and isthe typical technology used to provide active and reactive powerservices to grid 128.

In examples, converter 134 can be a “hybrid power conversion” system.The hybrid power conversion system can use the PCS topology on the AC(grid 128) connected side and the chopper/thyristor topology on the DCside connected to the electrolyzer of hydrogen production system 106.This will produce “non-clean” DC suitable for use by the electrolyzer toperform electrolysis at a lower cost, while providing a “clean” AC powercapable of adjusting phase angle and providing reactive power servicesto grid 128. It will be appreciated that this hybrid power conversionwill be capable of providing valuable grid services such as the reactivepower services typically provided by full PCS topology at a lower totalcost. Because the “hybrid power conversion” system can be connected togrid 128 and provide reactive services, it can be desirable to becertified to UL Standard UL1741 or equivalent. Examples of hybrid powerconversions systems for converter 134 are discussed further withreference to FIG. 10.

It will be appreciated that the electrolyzer of hydrogen productionsystem 106 can be receptive of water and DC electricity from converter134 to produce hydrogen gas and oxygen gas. Some examples of theelectrolyzer can also require an input of electrolyte, such as potassiumhydroxide. The hydrogen gas can proceed to hydrogen purification system136, hydrogen compressor 138, and into hydrogen storage system 110.Likewise, the oxygen gas can proceed to oxygen purification system 140and into oxygen storage system 112. A similar oxygen compressor (e.g.,compressor 356 of FIG. 8) can optionally be used. Although examples havebeen described herein as hydroxide electrolytic electrolyzes, it will beappreciated that the scope of the disclosure is not so limited, and iscontemplated to include other electrolyzer arrangements, such as polymerelectrolyte membrane (PEM) electrolysis units.

Hydrogen storage system 110 can include a salt cavern to store thehydrogen gas. In some examples, hydrogen storage system 110 can includeone or more lengths of pipe or pressure vessels such as “bullet” shapeor spheres that are highly pressurized to store the hydrogen. Examplesof hydrogen storage system 110 are described in greater detail withreference to FIGS. 11-16F.

The hydrogen gas within the hydrogen storage system 110 can be used as afuel, and provided to combustor 150 of gas turbine 114. Flow valves 142and 144 can be responsive to GTCC plant output controller 124 to providea flow of hydrogen and natural gas fuels to gas turbine 114. Under someconditions, controller 124 can command valves 142 and 144 such as toprovide only one fuel (either natural gas or hydrogen) to gas turbine114. Under other conditions, controller 124 can command valves 142 and144 such as to provide a blend of both natural gas and hydrogen to gasturbine 114.

Relative to natural gas, combustion of hydrogen occurs at a highertemperature. Higher temperature combustion can be expected to result inincreased production of oxides of nitrogen (NOx). In examples, theoxygen from oxygen storage system 112 can be provided, as “hot oxygen”,to inlet duct 164 of the HRSG 116 to reduce the production of NOx, suchas by using nozzle 300 of FIG. 9.

While examples of the disclosure have been described with regard to theuse of hydrogen as an energy storage medium, it will be appreciated thatthe scope of the disclosure is not so limited, and that other energystorage mediums can be created with excess renewable energy for lateruse as a fuel (or carrier of energy, the decomposition of which canyield a fuel, including hydrogen, for example), such as ammonia, forexample.

As is discussed below with reference to TABLE 1, integrated powerproduction system 100 can be operated to utilize available resources toproduce energy for direct consumption or storage, via production ofhydrogen that can be stored or electricity that can be stored. Inaddition, for example, use of renewable energy and hydrogen fuel can beincreased, either by using renewable energy sources when available orstored hydrogen produced during periods of low demand to reduce emissionof GTCC 104. Thus, for example, overall operation of GTCC 104 can besmoothed out to eliminate or reduce ramp up and ramp down periods ofinefficient and high mechanical demand operation.

FIG. 2 represents another view of a control approach of system 100 shownin FIGS. 1A and 1B. Master controller 108 can be in communicationthrough various plant controllers 154 to more specific set pointcontrollers 120-126 (FIGS. 1A and 1B) for one or more instances of GTCC104 and electrolyzers of hydrogen production system 106 within system100. FIG. 2 illustrates that different instances of electricityproducers, such as GTCC 104 and renewable wind electricity sources 130,and hydrogen production systems 106 can be combined to provideintegrated power production system 100.

As is discussed with reference to FIG. 3, GTCC 104 can be combined withhydrogen production system 106 to permit HRSG 116 to heat electrolyzer201 and electrolyzer 201 to provide hydrogen to gas turbine 114.

As is discussed with reference to FIG. 4, GTCC 104 can be combined withhydrogen production system 106 and renewable wind electricity sources130 to provide power to battery 222 for use during intermittent downtimeof renewable wind electricity sources 130 as well as frequency support,and oxygen can be expanded to allow cooling of electrolyzer 201. Inexamples, battery 222 can be replaced with another electrolyzer 201.

As is discussed with reference to FIG. 5, a plurality of electrolyzers201 can be connected to a plurality of converters 134 and heating orcooling loop 230 to selectively heat or cool one or more ofelectrolyzers 201 and converters 134.

As is discussed with reference to FIG. 6, HRSG 116 can be combined withelectrolyzer 201 to provide heating, steam turbine 118 to providesynchronous condensing, and hydrogen compressors 138 and 254 to providehydrogen storage and surge capabilities for coordinating burning ofhydrogen and natural gas in gas turbine 114.

As is discussed with reference to FIG. 7, any or all of hydrogenproduction system 106 of FIGS. 1-6 can be connected to hydrogen storagesystem 110, which can take on the form of various underground storagefacilities described with reference to FIGS. 11-16F.

The various sub-systems described with reference to FIGS. 3-7 can becombined into a configuration of integrated power production facility100 that are jointly operated by master controller 108 to smooth outperiods of high and low demand on grid 128 by producing electricity forshort term storage in batteries and hydrogen for long term storage instorage vessels during periods of low grid demand for later use duringperiods of high grid demand, while simultaneously lowering emissions viaefficient use of available renewable energy sources and production ofhydrogen for burning in gas turbine engines.

FIG. 3 is a schematic diagram illustrating system 200 comprisingcombined cycle power plant 104 (FIG. 1B) having gas turbine 114 (FIG.1B), HRSG 116 and hydrogen production system 106. Hydrogen productionsystem 106 can comprise electrolyzer 201. Hydrogen production system 106can be connected to hydrogen receiving tank 110 and power conversionequipment including converter 134. FIG. 3 represents another view ofsome components suitable for use in integrated power production system100 of FIGS. 1A and 1B. FIG. 3 illustrates a system for utilizing heatfrom the exhaust gas of turbine 114, as captured by HRSG 116, withintegrated power production system 100. System 200 can be connected tomaster controller 108 (FIG. 1).

Power line 203 can be used to deliver electricity to hydrogen productionsystem 106 from grid 128 (FIGS. 1A and 1B) to, for example, controlgeneration of hydrogen with electrolyzer 201 based on other parametersof system 100. Hydrogen generated by hydrogen production system 106 canbe provided to hydrogen receiver tank 110 via hydrogen line 204.Hydrogen compressor 138 can be used to increase a pressure of hydrogenand move hydrogen to another location. Hydrogen compressor 138 can feedgas turbine 114 via line 206A and another process, such as industrial orfuel uses, via line 206B. Additionally, compressed hydrogen can be sentback to hydrogen receiver tank 110 via line 208 and valve 210.Furthermore, hydrogen can be provided to HRSG 116 via line 212 to, forexample, provide supplemental firing capabilities and the like.

Gas turbine 114 can be configured to provide exhaust gas to HRSG 116 asdiscussed with reference to FIGS. 1A and 1B. However, gas turbinesconfigured to receive hydrogen from hydrogen production system 106 canbe located anywhere on grid 128 away from hydrogen production system106. Gas turbine 114 can comprise a multiple shaft gas turbine engineand can be connected to generator 154 via clutch 214, such thatgenerator 154 can be configured to operate as a synchronous condenser.For example, clutch 214 can be operated by controller 108 to disconnectgenerator 154 from gas turbine 114 and generator 154 can be providedwith AC power from grid 128 to alter or adjust the phase angle (<) ofgrid 128. Gas turbine 114 can be configured to operate as a simple cycleelectrical producer or in conjunction with a combined cycle facility.Gas turbine 114 can be located away from electrolyzer 201. Gas turbine114 can be configured to use hydrogen from hydrogen production system106, hydrogen storage 110 of FIGS. 1B, 3 and 7, and other hydrogensources or storage systems, such as those shown in FIGS. 11 to 16F.

Heat from HRSG 116 can advantageously be used by other industrialprocesses that are located with or near system 100, such as for chemicalproduction or for facility environmental thermal control, as isillustrated in FIG. 8.

In the illustrated example, electrolyzer 201 of hydrogen productionsystem 106 can be heated by steam or water from HRSG 116 using fluidlines 202. As such, electrolyzer 201 can be maintained in a warmed stateor a standby mode whereby electrolyzer 201 can be brought up tooperating capabilities rapidly as compared to starting from ambienttemperature, thereby providing rapid response production of hydrogen.Fluid can circulate between HRSG 116 and hydrogen production system 106using fluid lines 202 to provide heating, or cooling, as desired. Inexamples, heat can be provided to hydrogen production system 106 from anindustrial process, or other heat sources. In additional examples,cooling can be provided to hydrogen production system 106 by a source ofcooling fluid from other than HRSG 116, such as expanded oxygen.

FIG. 4 is a schematic diagram illustrating system 220 comprising heatrecovery steam generator 116 connected to hydrogen production system106, which is also connected to battery 222 and wind electricity source130. Hydrogen production system 106 can be connected to cooling system224, which can comprise expansion turbine 226, electrical generator 228and heat exchanger 229. Hydrogen production system 106 can be connectedto hydrogen receiving tank 110 and power conversion equipment includingtransformer 133 and converter 134. Battery 222 can be connected to windelectricity source 130 via power conversion equipment includingtransformer 133 and converter 134. FIG. 4 represents another view ofsome components suitable for use in integrated power production system100 of FIGS. 1A and 1B. FIG. 4 illustrates a system for storingelectricity at battery 222 to, for example, provide power load andfrequency support capabilities and for using pressurized O2 (or H2) fromelectrolyzer 201 for generating electricity and cooling one or both ofconverters 134 and electrolyzer 201. System 220 can be connected tomaster controller 108 (FIG. 1) to, for example, control flow of fluid toelectrolyzer 201 and operation of battery 222 based on other parametersof system 100. Power line 203 can be used to deliver electricity tohydrogen production system 106 and battery 222 from grid 128 (FIGS. 1Aand 1B).

There are various manners in which the oxygen from hydrogen productionsystem 106 can be advantageously integrated with other components withinintegrated power production system 100. For example, oxygen from oxygenstorage system 112 (FIGS. 1A and 1B) or directly from hydrogenproduction system 106 can be expanded, such as through an orifice,expander valve, or through expanding turbine 226. It will be appreciatedthat expansion of pressurized oxygen will result in a reduction oftemperature. This reduced temperature oxygen, can be used as a fluid tocool converter 134 connected to hydrogen production system 106 via heatexchanger 229. Similarly, the reduced temperature oxygen can be used tocool electrolyzer 201, which can be beneficial in expediting cooldown sothat maintenance and other procedures can be performed. Fluid lines forheat exchanger 229 can include various valves operable by controller 108to control flow of the reduced temperature oxygen based on gridconditions. In examples, expanding turbine 226 can be connected toelectrical generator 228 to provide additional electricity to grid 128.In examples, expanding turbine 226 can be connected to hydrogencompressor 138 (FIG. 3) to provide rotational power to hydrogencompressor 138, thereby also recovering energy expended by system 220 incooling electrolyzers 201. In such configurations, expanding turbine 226can increase total output or reduce auxiliary loads, to enhance systemefficiency.

As discussed herein, electrolyzer 201 can be heated using heat from HRSG116, industrial process heat, district heating sources, commercialbuilding heat and the like.

Battery 222 can be used to store electricity generated by windelectricity source 130. Battery 222 can additionally assist in bothpower load and frequency support capability when, for example, powerfrom wind electricity source 130 may be reduced. Controller 108 canprovide regulation up or down, frequency up or down, or reactive powermanagement. The oxygen cooling described above can also be used forthermal management of battery 222. In examples, battery 222 can beincluded at the location of hydrogen production system 106.

FIG. 5 is a schematic diagram illustrating fluid loop 230 forelectrolyzer bank 232, which can be connected to rectifier bank 234.Fluid loop 230 can comprise heat exchanger 229, fluid lines 236 andelectrolyzer lines 238. Electrolyzers 201 can be connected to powerconverters 134 via electrical lines 240. Fluid loop 230 can providethermal input (e.g., heat) or cooling to electrolyzers 201 and powerconverters 134 can provide electrical input to electrolyzers 201 suchthat electrolyzers 201 can produce hydrogen and oxygen outputs (notshown in FIG. 5). FIG. 5 represents another view of components suitablefor use with integrated power production system 100 of FIGS. 1A and 1B.FIG. 5 illustrates how electrolyzers 201 can be maintained in a readystate using heat from loop 230 or can be quickly cooled down after useusing loop 230. Loop 230 can be connected to master controller 108(FIG. 1) to, for example, control flow of fluid through loop 230 basedon other parameters of system 100. Power line 203 can be used to deliverelectricity to electrolyzers 201 via converters 134 individually fromgrid 128 (FIGS. 1A and 1B).

During those times when one or more of electrolyzers 201 are notoperating to produce hydrogen and oxygen, it can be desirable to provideheat to at least one of electrolyzers 201 to maintain such electrolyzerin a ready state to quickly and efficiently commence production ofhydrogen. There are various manners in which the thermal management ofelectrolyzers 201 can be advantageously integrated with other componentswithin the integrated system 100. In examples, the heat can be providedvia HRSG 116 (See FIG. 3), which can provide steam or water to loop 230at temperatures sufficient to maintain electrolyzers 201 is a standbymode. In examples, heat can be provided by converters 134 of operatingelectrolyzers 201 to keep in a ready state electrolyzers that are notcurrently operating, thereby additionally cooling the converters 134associated with the operating electrolyzers 201. In additional examples,the heat can be provided via dedicated heating devices 242. In examples,heating devices 242 can comprise resistance heaters, which can beprovided with electrical power from grid 128 (FIGS. 1A and 1B) oranother source. In examples, heating devices 242 can comprise burnersthat can be provided with hydrogen fuel via electrolyzers 201 forcombustion.

Heat exchanger 229 or another heat exchanger can additionally beconnected to a loop of cooling fluid, such as expanded oxygen fromturbine 226 of FIG. 4. The expanded oxygen can be used to coolelectrolyzers 201, such as after electrolyzers 201 are shut down so to,for example, allow for maintenance of electrolyzers 201 sooner aftershutdown. In additional examples, converters 134 can be provided withcooling via heat exchanger 229 of FIG. 4.

Although not illustrated in FIG. 5, loop 230 can be connected toconverters 134 via additional fluid lines to provide cooling ofconverters 134 to, for example, allow converters 134 to operate atefficient temperatures.

Each of these examples discussed with reference to FIG. 5 representsynergistic uses of thermal exchange to facilitate one or more ofcooling of converters 134 and heating electrolyzers 201 in standby mode.

FIG. 6 is a schematic diagram illustrating heat recovery steam generator116 connected to electrolyzer 201 and hydrogen surge system 250.Hydrogen surge system 250 can comprise hydrogen storage system 110,hydrogen compressor 138, hydrogen surge tank 252, hydrogen surgecompressor 254, hydrogen purifier 136, and mixing tank 258. FIG. 6represents another view of components suitable for use with integratedpower production system 100 of FIGS. 1A and 1B. FIG. 6 illustrates howhydrogen generated with electrolyzer 201 can be incorporated intoelectric power generation of integrated power production system 100.System 250 can be connected to master controller 108 (FIG. 1) to, forexample, control flow of hydrogen and natural gas to gas turbine 114.Power line 203 can be used to deliver electricity to electrolyzer 201from grid 128 (FIGS. 1A and 1B).

HRSG 116 can comprise low, medium and high temperature steam circuitswithin steam circuit 260 configured to heat water and provide steam tosteam turbine 118. Electrolyzer 201 can output hydrogen at line 262 toprovide hydrogen to purifier 136. Hydrogen from purifier 136 can beprovided to hydrogen storage system 110 via line 264. Hydrogen storagesystem 110 can comprise a tank or the like, as is discussed withreference to FIG. 7 and FIGS. 11-16F. Hydrogen compressor 138 canprovide compressed hydrogen to surge tank 252 via lines 266A and 266B.Hydrogen within surge tank 252 can be connected to surge compressor 254via line 268 and mixing tank 258 via line 270. Mixing tank 258 can beconnected to a source of natural gas via line 272 and the combustor ofgas turbine 114 via line 274. Hydrogen surge system 250 can additionallycomprise valves 276A, 276B and 276C that can be operated by controller108 to control flow of fuel through system 250.

There are various manners in which thermal management of the componentscan be advantageously integrated with other components within theintegrated system 100. For example, feedwater in HRSG 116 within circuit260 can be used to heat electrolyzer 201. Additionally, electrolyte ofelectrolyzer 201 can be heated by exhaust of gas turbine 114 via aneconomizer coil within HRSG 116. Alternatively, electrolyzers 201 can becooled via feedwater of HRSG 116, depending on where the feedwater istaken out of HRSG 116. In an additional example, cooling circuits forgas turbine 114 can be used to heat electrolyzer 201.

Steam turbine 118 can be connected to generator 156 via clutch 160,allowing generator 156 to spin freely from steam turbine 118 andfunction as a synchronous condenser for reactive power and/or voltagesupport. For example, clutch 160 can be operated by controller 108 todisconnect generator 156 from steam turbine 118 and can be provided withAC power from grid 128 to alter or adjust the phase angle (<D) of grid128.

Hydrogen compressor 138 can be driven by a variety or combination ofmotive sources. For example, hydrogen compressor 138 can be driven by anelectric motor. In other examples, hydrogen compressor 138 can be drivenby steam provided by HRSG 116 or other heat sources, such as converters134. Other examples can include a mechanical drive from gas turbine 114or steam turbine 118 to hydrogen compressor 138.

FIG. 7 is a schematic diagram illustrating hydrogen storage system 110.Hydrogen storage system 110 can comprise storage tank 280 and pipeline282. FIG. 7 represents another view components suitable for use withintegrated power production system 100 of FIGS. 1A and 1B. FIG. 7illustrates that hydrogen can be stored in various containers, includingtank 280, located far away from hydrogen production system 106 viapipeline 282. There are various manners of providing hydrogen storage110, such as those illustrated in FIGS. 11 to 16F. In the example ofFIG. 7, hydrogen storage 110 can comprise a pipeline of various lengths,with the pipeline pressurized above the typical operating pressure toaccommodate storage of hydrogen. System 110 can be connected to mastercontroller 108 (FIG. 1) to, for example, control flow of hydrogen to andfrom tank 280.

FIG. 8 is a schematic diagram illustrating integrated power productionsystem 100 of FIGS. 1A and 1B operable in conjunction with industrialfacility 350. It will be appreciated that industrial facility 350 can beproductive of one or more of various fuel, chemical, or material (suchas steel, aluminum, etc.) products as an output product 376. Industrialfacility 350 can comprise controller 352 and transformer 354. As shownin FIGS. 1A and 1B, integrated power production system 100 can compriseoxygen storage system 112 and oxygen purification system 140. Oxygenpurification system 140 can be configured to provide purified oxygen tooxygen storage system 112 via compressor 356. Industrial facility 350can have a plurality of inputs, including oxygen input line 360, or 362,hydrogen input line 366, saturated steam line 368, and pressurized steamline 370.

Oxygen input line 360 can connect to system 100 at output ofelectrolyzer 201. Oxygen compressed by compressor 356 can flow intooxygen storage system 112, after being purified by purifier 140. Oxygenfrom oxygen storage system 112 can pass to industrial facility 350 atline 362. Oxygen can further pass from oxygen storage system 112 back tosystem 100 at HRSG 116 via extension of line 364. Hydrogen input line366 can connect to system 100 at output of hydrogen purification system136. Saturated steam line 368 can connect to system 100 between HRSG 116and heat exchanger 158. Pressurized steam line 370 can connect to system100 at the inlet of steam turbine 118 or any drum of HRSG 116, as wouldbe appreciated by one of skill in the art.

Industrial facility 350 can receive electrical power from grid 128(FIGS. 1A and 1B) via power line 372 which may have its voltage changedvia transformer 354. Controller 352 can be in communication with mastercontroller 108 (FIGS. 1A and 1B) via control line 374. Industrialfacility 350 can be operated using inputs 360-366 and other inputs tooutput product 376. Controller 352 can work in conjunction withcontroller 108 to produce output product 376 using resources fromintegrated power production system 100 based on availability ofhydrogen, oxygen and steam due to conditions of grid 128. As such, lines360-370 can include valves that can be operated by controller 108 andcontroller 352.

FIG. 9 is a schematic illustration of thermal nozzle 300 that can beused to produce hot oxygen. Thermal nozzle 300 can comprise housing 302,injector 304, inlet port 306 and outlet orifice 308. Housing 252 cancomprise chamber 310 to which openings 312 can connect and into whichinjector 304 can be inserted through port 314. Port 314 can beconfigured to axially align injector 304 with outlet orifice 308.Injector 304 can comprise a tube having lumen 316 and discharge orifice318. Thermal nozzle 300 can receive oxygen and a fuel. In examples,thermal nozzle 300 can be configured similar to thermal nozzlesdescribed in U.S. Pat. No. 5,266,024 to Anderson, the entirety of whichis incorporated herein by reference thereto. However, thermal nozzle 300additionally includes openings 312. As described in U.S. Pat. No.5,266,024 combustion of the fuel in the oxygen rich environment canproduce oxygen jet 320 of hot oxygen that produces mixing 322 in theaxial direction. The additional of openings 312 can further provideoxygen jets 324 of hot oxygen that produce mixing 326 in the radialdirection.

Oxygen jets 320 and 324 can be expelled from thermal nozzle 300 with thefollowing properties: high velocity, typically greater than 750 m/s tocreate recirculation and mixing 322 and 326, and a high concentration ofradicals to support reaction kinetics. This drives lower temperature“oxidation” reactions vs. higher temperature “combustion” reactions.Demonstrated reactivity and kinetics are due to injection of highlyreactive gas. In examples, the preheated oxygen destroys CO and NOxprecursors (NH3 and HCN) with little or no generation of NOx.

With reference back to FIGS. 1A and 1B, thermal nozzle 300 can bedisposed directly within inlet duct 164 of HRSG 116. In examples, theoxygen provided to thermal nozzle 300 can be provided directly fromoxygen storage system 112. In examples, the oxygen provided by oxygenstorage system 112 can be in thermal communication with one or more of(i) the heated water of HRSG 116, (ii) heated steam of HRSG 116; (iii)the exhaust gas flowing through HRSG 116. Any suitable heat exchangercan be used to transfer heat between the oxygen and the foregoingstreams.

The example nozzle of U.S. Pat. No. 5,266,024 can provide a highvelocity output that can be well suited for injection into a generallylaminar flow stream, such as within a pipe, intended to provide rapidmixing of the hot oxygen within the laminar flow stream. Openings 312can function as output orifices that are disposed in multiple locationsaround housing 302 of nozzle 300. It is contemplated that openings 312provide enhanced mixing of hot oxygen within a large turbulent zone,such as within inlet duct 164 of HRSG 116.

As shown in FIG. 1B, in examples, oxygen provided by oxygen storagesystem 112 can be provided directly to an inlet of gas turbine 114. Theintroduction of oxygen into gas turbine 114 inlet can reduce thepercentage composition of nitrogen in the gas turbine mass flow, andthereby reduce NOx production and emission. The oxygen from oxygenstorage system 112 can be provided directly to the inlet of gas turbine114 in the form of hot oxygen produced by thermal nozzle 300 asdescribed above. In examples, the oxygen from oxygen storage system 112can be provided directly to inlet duct 164 in the condition of oxygenstorage system 112 (i.e. absent use of the thermal nozzle 300). Otherexamples can include other equipment to alter the condition of theoxygen prior to introduction into inlet duct 164. Examples of suchequipment can include pumps to increase the pressure (and/ortemperature) of the oxygen from oxygen storage system 112, expansionnozzles or valves to decrease the pressure (and/or temperature) of theoxygen from oxygen storage system 112, as well as heat exchangers thatcan be located at various stages of heat recovery steam generator 116 toeither heat or cool the oxygen supplied from oxygen storage system 112.Other examples can include thermal communication between oxygen fromstorage system 112 with other electronic or process components that canbenefit from an exchange of heat, such as controllers 108, 120-126,power conversion equipment 133, 134, hydrogen production system 106, orgas turbine 114.

TABLE 1 Case 1 2 3 4 5 6 Case Shut down Parked GTCC ProducingElectrolyzer Producing H2 Condensing to Description GTCC over overnight,max power, running 50%, on cheap power weekend, Cheap Power but a bigGTCC down electricity transition Cheap Power producing H2, industrialload from grid, grid producing H2, power trips off then demands butdemand goes more power emergency up and price call for Max begins Powerincreasing GTCC Start Cold, 0% Min Load Max load Down FSNL on H2 GTCC onCondition Load (~30%) on (100%) on sync natural gas mix of condensinghydrogen and natural gas Electrolyzer Hot, 100% Hot, 100% Warm, 0%Running 50%, Full H2 Producing H2 Start Load Load Load 50% coldproduction as part of grid Condition (assuming support electrolyzer warmand ready) Signal from Deliver Max Deliver Max Reduce Power RenewableNeed more Load demand Grid Power Power nearly power drops, powerinstantly signal to reduce load GTCC Cold Start to Ramp to Slow rampStays in Ramp up to Start to ramp Response 100% Load to 100% Load atdown to min standby until load, blending up - first with optimizefastest rate load grid needs in NG if NG, then LTSA cost that does not(whatever rate power needed transition to (not fast start) impact LTSAhas no impact H2 to LTSA) Electrolyzer Fast shut Fast shut Fast start toShuts down as Reduce H2 Start to ramp Response down. . . releasing down.. . releasing absorb as needed to Production, down that load that loadmuch load as balance load which appears back to grid, back to grid,quickly as to be GT mimicking a mimicking a possible. . . production (infacility fast facility fast allowing GTCC to net) start. start. rampslowly.

As summarized in TABLE 1, there are various potential operatingconditions that can be provided via collaboration between mastercontroller 108 with the other controllers 120, 122, 124, 126, as well asvarious other controllers of the various subsystems shown with respectto FIGS. 3-7 and 10. Examples of such controllers are described withreference to FIG. 29.

Case 1: GTCC plant 104 is shut down, such as over a weekend, when powerdemand by consumers 152 is comparatively low. Surplus power provided byrenewable electricity sources 130, 132 (beyond that required byconsumers 152) is provided via grid 128 to the transformer 133,converter 143, and electrolyzer of hydrogen production system 106 toproduce hydrogen to be stored within hydrogen storage system 110.Because GTCC plant 104 has been shut down, it is in a comparatively“cold” thermal state. Within such “cold” thermal state, it is desired toslowly ramp up the power output of GTCC plant 104, in order to minimizethermal gradients and stresses. However, as can sometimes be the case,grid 128 can be called upon to provide for a large demand forelectricity, perhaps from a large industrial consumer starting itsfactory. Ordinarily, GTCC plant 104 can be called upon for a “faststart” that can impose high thermal gradients and stresses within gasturbine 114. The integration of components of system 100 provides analternate solution that allows gas turbine 114 to have a preferable slowstart, while immediately providing the large demand of electricity. Inthis case, an electrolyzer of hydrogen production system 106 can be shutdown immediately or as soon as is practicable, with the energypreviously consumed by the electrolyzer now immediately or as soon as ispracticable being available for grid 128 to distribute from renewablesources 130, 132 to consumers 152. At the same time, while theelectricity previously consumed by the electrolyzer is made available toconsumers 152, GTCC plant 104 can begin warm-up processes with apreferred ramp up rate. That is, the near-immediate shut down of theelectrolyzer simulates a “fast start” by GTCC 104 without imposing thehigh thermal gradients and stresses upon gas turbine 114 of GTCC 104.

Case 2: GTCC 104 is “parked”, running at a minimum (approximately 30%)load, running on natural gas. Because demand for power on grid 128 islow, power is cheap, and the electrolyzer of hydrogen production system106 can be running at full load, consuming power from grid 128 and/orGTCC 104 to produce hydrogen gas to be stored in hydrogen storage system110. As with Case 1, an immediate increase in power from consumers 152can be desired. Again, the electrolyzer can be quickly shut downproviding an apparent near immediate supply of power to grid 128.Because GTCC 104 is running at minimum load, its capability to producepower can be ramped up faster than that of Case 1. Again, the demand forrapid power can be fulfilled by curtailing consumption of theelectrolyzer, rather than a fast ramp of GTCC 104. It will beappreciated that if, instead of running on natural gas, GTCC 104 is“parked” and running on hydrogen, the emissions can be merely watervapor, with no carbon dioxide.

Case 3: Demand for power is high, but drops rapidly. Consider that alarge industrial consumer 152 suddenly trips off, and the demand forpower from grid 128 drops suddenly. Because demand was high, GTCC 104operates at base (full) load, and the electrolyzer of hydrogenproduction system 106 can be producing not very much hydrogen (notconsuming very much energy from grid 128). If electrolyzers are kept ina warm state (such as via heat from HRSG 116, as described herein withreference to FIGS. 3-6, for example), the electrolyzers can immediatelyincrease to 100% production of hydrogen, and begin to immediatelyconsume the power previously consumed by the large industrial consumer152. That is, rapid start of the electrolyzers can quickly replace thedrop in demand from industrial consumer 152. As such, GTCC 104 caninitiate a slow ramp down (in balance with the electrolyzers of hydrogenproduction system 106), to reduce cool-down thermal gradients on GTCC104. Excess power consumed by electrolyzers can be stored in the form ofhydrogen in hydrogen storage system 110 for later conversion toelectricity by GTCC 104.

Case 4: GTCC 104 is off, and the electrolyzers of hydrogen productionsystem 106 are running at partial load. As the availability of renewablepower from sources 130, 132 declines, the electrolyzers can reducehydrogen production to maintain balance of grid 128.

Case 5: GTCC 104 is operating at full speed with no load (up totemperature and speed, but no electricity production), and running onhydrogen from hydrogen storage system 110. Grid 128 recognizes anincrease in power demand, and responsive there to, GTCC 104 can begin toramp up to load while the production of hydrogen by the electrolyzers ofhydrogen production system 106 can decrease. If there is a shortage ofhydrogen available to power gas turbine 114, GTCC 104 can begin to openthe natural gas flow via valve 144.

Case 6: Generator 154 of gas turbine 114 is operating as a synchronouscondenser, and the electrolyzers of hydrogen production system 106 areconsuming power from grid 128 to maintain grid 128 balance and producehydrogen gas. As grid 128 begins to sense an increasing demand forelectricity, master controller 108 can direct the other controllers120-126, as well as other controllers of the sub-systems of FIGS. 3-7and 10, to ramp down the electrolyzers and ramp up GTCC 104, initiallyon natural gas fuel via valve 144, to be subsequently replaced withhydrogen gas via storage system 110 and valve 142.

Although 6 discrete cases are described above, it will be appreciatedthat the scope of the disclosure is not so limited, and includes variouscombinations of each or all of the above cases, such as any intermediateoperating conditions between those specific conditions described, and tooperate on all natural gas, all hydrogen, or any combination of the two.

FIG. 10 is a schematic diagram of hydrogen generation system 400comprising electrolysis pack 402, battery pack 404 and renewable energyproducers 405 connected to grid 128 via bi-directional inverter 406 andDC-DC inverters 408A and 408B. System 400 can further comprise firstbreaker 410A, second breaker 410B, third breaker 410C, fourth breaker410D, fifth breaker 410E and sixth breaker 410F. Power from grid 128 canbe transmitted to system 400 through transformers 412A and 412B.Bi-directional inverter 406 can comprise AC converter 414 and DCconverter 416. DC-DC inverter 408A can comprise first converter 418A andsecond converter 420A. DC-DC inverter 408B can comprise first converter418B and second converter 420B. Electrolysis units 402 can be connected(via their output of Hydrogen) to GTCC 422, which can be connected togenerator 424. Electrolyzer units 402 can also be connected to oxygenconsumer 426.

Transformer 412A can transfer power from grid 128 to hydrogen generationsystem 400. Likewise, transformer 412B can transfer power fromtransformer 412A to converter 406. B-directional inverter 406 canconvert alternating current from transformer 412A to direct current viaAC converter 414. Electrolysis pack 402 can comprise a plurality ofelectrolysis units 428 that can be electrically connected together, suchas in series or parallel, to receive current from inverter 406. Eachelectrolysis unit 428 can be configured to convert an input of water(H20) into hydrogen (H2) and oxygen (O2) gas using electricity, such asvia DC.

Inverter 408A can convert DC from inverter 406 from one voltage toanother voltage that is suitable for use with battery pack 404. Batterypack 404 can comprise a plurality of battery units 430 that can beelectrically connected together, such as in series or parallel, toreceive or provide current from or to, respectively, inverter 408A.

Renewable energy producers 405 can comprise a plurality of instances 432of one or both of solar panels and wind turbines that can be connectedtogether in series or parallel to provide electrical input to inverter408B. Inverter 408B can convert DC from one voltage to another, such asconverting DC from renewable energy producers 405 to a voltage suitablefor use with inverter 406.

TABLE 2 Breaker Positions Local Solar/Wind - GTCC Breaker 6 - ClosedOpen State Breaker 5 State State Service 1, 2, 4 3 Batteries Breaker 5open, Breaker 6 open with Excess renewable charging PV not providingGTCC shut down or grid power storage from Grid power. Breaker 6 closedand GTCC using batteries. closed, PV adding operating at min loadBenefits.: Store to charging for stand by services. excess power frombatteries grid that exceeds electrolysis capacity and can be used laterto feed to grid or electrolysis. 1, 2, 4 3 Batteries Breaker 5 open,Breaker 6 Open GTCC Traditional battery discharging PV not providingshut down, batteries energy storage or connected power. offeringtraditional services. as stand by services or acting as Benefits: Peakto Grid spinning reserve for power, Freq. Reg., GTCC. Breaker 6 Voltage,Reactive closed, GTCC and power, Shifting, batteries adding powerNon-spinning/spinning to the grid. reserve. . . traditional BESSservices. 1 2, 3, 4 PCS grid Breaker 5 open, Breaker 6 open, GTCCReactive power connected PV not providing shut down. Breaker 6 services.power. closed, power, reactive services, inertia. 1, 4 2, 3 PCS gridBreaker 5 closed, Breaker 6 open, GTCC Reactive power connected, PVcharging shut down. Breaker 6 services. PV battery batteries. closed,power, reactive connected services, inertia. 1, 2, 3 4 ElectrolysisBreaker 5 open, Breaker 6 open, GTCC Hydrogen and Grid PV not providingshut down. Breaker 6 Oxygen produced connected. power. Breaker 5 closed,GTCC for long duration closed, PV adding operating at min load storage.to Hydrogen for stand by services. production. 3, 4 1, 2 ElectrolysisBreaker 5 open, Breaker 6 open, GTCC Recover excess connected to PV notproviding shut down. Breaker 6 power for Batteries. power. Breaker 5closed, GTCC electrolysis for closed, PV adding operating at min loadHydrogen and to Hydrogen for stand by services. Oxygen productionproduction. (shifting short term storage to long term storage). 1, 2, 3,4 Hydrogen Breaker 5 open, Breaker 6 open, GTCC Balance electrolysisproduction PV not providing shut down. Breaker 6 for Hydrogen and andpower. Breaker 5 closed, GTCC Oxygen production simultaneous closed, PVadding operating at min load for long duration battery to Hydrogen forstand by services. storage and charging charging production and batteryenergy battery charging. storage for short duration storage.

In a first state, breakers 410A-4101D can be closed. In such a state,electrolysis units 428 can be actively converting electricity and waterto hydrogen and oxygen and battery units 430 can be simultaneouslycharging. The first state can be used when hydrogen and oxygenproduction is being stored, such as in hydrogen storage system 110 andoxygen storage system 112 (FIG. 1), for long term storage and energy isbeing stored in battery units 430 for short term storage. The firststate can occur when there is an excess of energy available to grid 128,such as when renewable energy sources, e.g., wind electricity sources130 and solar electricity sources 132 (FIG. 1), are operating at highcapacity.

In the first state, breakers 410E and 410F can be open or closed. Withbreaker 410E open, renewable energy sources 405 can be in anon-producing state. With breaker 410E closed, renewable energy sources405 can be producing and providing electricity to, for example, producehydrogen with electrolysis units 428 and store power in battery units430. With breaker 410F open, GTCC 422 can be shut down. With breaker410F closed, GTCC 422 can be operating for standby services, such as atminimum load.

In a second state, breakers 410A, 410B and 410D can be closed andbreaker 410C can be open. In such a state, excess power from grid 128can be stored in battery units 430. Thus, excess power from grid 128that during periods when it may be desired not to operate electrolysispack 402, can be stored for later usage with electrolysis pack 402.

In the second state, breakers 410E and 410F can be open or closed. Withbreaker 410E open, renewable energy sources 405 can be in anon-producing state. With breaker 410E closed, renewable energy sources405 can be producing to, for example, store power in battery units 430.With breaker 410F open, GTCC 422 can be shut down. With breaker 410Fclosed, GTCC 422 can be operating for standby services, such as atminimum load.

In a third state, breakers 410A, 410B and 410D can be closed and breaker410C can be open. In such a state, battery units 430 can be dischargingto grid 128 or can be connected to grid 128 in a standby mode. Thus,battery units 430 can be used for energy storage services. The benefitsof operating in the third state include peak power (e.g., providingadditional power from battery units 430 to grid 128), frequencyregulation (e.g., using battery units 430 to adjust the frequency ofgrid 128), voltage, reactive power, including traditional Battery EnergyStorage Systems (BESS) services.

In the third state, breaker 410E can be open with renewable energysources 405 not providing power. With breaker 410F open, GTCC 422 can beshut down, battery units 430 can be offering traditional services oracting as spinning reserve. With beaker 410F closed, GTCC 422 andbattery units 430 can be adding power to grid 128.

In a fourth state, breaker 410A can be closed and breakers 410B, 410Cand 410D can be open. In such a state, bi-directional inverter 406 canbe connected to grid 128 to provide power conversion system services andto provide reactive power services.

In the fourth state, breaker 410E can be open with renewable energysources 405 not providing power. With breaker 410F open, GTCC 422 can beshutdown. With breaker 410F closed, GTCC 422 can be providing power,reactive services and inertia.

In a fifth state, breakers 410A and 410D can be closed and breakers 410Band 410C can be open. The fifth state can be useful for providing powerconversion system services to grid 128, providing reactive powerservices, and connecting renewable energy sources 405 to battery units430.

In the fifth state, breaker 410E can be closed so that renewable energysources 405 can charge battery units 430. With breaker 410F open, GTCC422 can be shut down. With breaker 410F closed, GTCC 422 can beproviding power, reactive services and inertia.

In a sixth state, breakers 410A, 410B and 410C can be closed and breaker410D can be open. In such a state, system 400 can be electrolysis gridconnected. The sixth state can be useful for hydrogen and oxygenproduction for long duration storage (e.g., via storage of hydrogen andoxygen in systems 110 and 112, respectively).

In the sixth state, breakers 410E and 410F can be open or closed. Withbreaker 410E open, renewable energy sources 405 can be not producing.With breaker 410E closed, renewable energy sources 405 can be producingto, for example, provide power to electrolysis units 428 to producehydrogen. With breaker 410F open, GTCC 422 can be shut down. Withbreaker 410F closed, GTCC 422 can be operating for standby services,such as at minimum load.

In a seventh state, breakers 410C and 410D can be closed and breakers410A and 410B can be open. In such a state, electrolysis pack 402 can beconnected to battery pack 404. The seventh state can be useful forrecovering excess power stored in battery units 430 for use withelectrolysis units 422 to produce hydrogen and oxygen, thereby shiftingshort term storage to long term storage (e.g., via storage of hydrogenand oxygen in systems 110 and 112, respectively).

In the seventh state, breakers 410E and 410F can be open or closed. Withbreaker 410E open, renewable energy sources 405 can be in anon-producing state. With breaker 410E closed, renewable energy sources405 can be producing to, for example, provide power to electrolysisunits 428 to produce hydrogen. With breaker 410F open, GTCC 422 can beshut down. With breaker 410F closed, GTCC 422 can be operating forstandby services, such as at minimum load.

FIG. 10 illustrates a system where electrolysis units 428 can beintegrated into system 100. System 400 can provide a DC sub-systemwithin breaker 410A that is not connected to grid 128 such that system400 can operate independent of grid 128. Thus, energy from renewableenergy producers 405 can be stored in batteries or directly used byelectrolysis units 428. The inclusion of battery units 430 canadditionally be used to reduce the number of electrolysis units 428 orwear and tear on electrolysis units 428. For example, battery units 430can be used to maintain electrolysis units 428 in an operating state orin a warmed-up state when electricity from renewable energy producers405 or grid 128 is not available, thereby reducing cycling ofelectrolysis units 428. In examples, the components of system 400 cancomprise components of FIGS. 1A-9 having similar names with differentreference numerals. For example, electrolysis units 428 can compriseelectrolyzers 201 and battery units 430 can comprise battery 222.

Storage Systems

The present application additionally discloses multiple storages systemsthat can be used for hydrogen storage, means and methods for installingstorage systems and ways of connecting such storage systems tointegrated power production facilities.

It is known to store hydrogen, as well as other gases, in variousstorage vessels. Common storage vessel arrangements include forged tubesthat can be certified to ASME and/or DOT standards that incorporatetransportation safety requirements, particularly for vessels that can beportable. These storage vessels can incorporate specific designfeatures, such as flanged and/or hemispherical ends to meet suchstandards. Vessels with such margins of safety and certifications areexpensive to produce.

The present disclosure provides a plurality of configurations forstationary pipelines that can be safe, easy to install and inexpensive.Stationary pipelines, via pressurization above standard pressures, canbe used as storage vessels for hydrogen. Additionally, where pipelinescannot be readily available or in use, standard pipes can be arranged asstorage containers, both above and/or below ground.

FIG. 11 depicts vertically disposed piping system 500 that can beutilized as a gaseous storage system, such as to store hydrogen, forexample. Piping system 500 can include various subsystems to provide andmaintain acceptable amounts and pressures of the hydrogen, includingcompressor 505, one or more venting sub-systems 510, vent 512, valves514A-514G, appropriate sensors 515, such as pressure transducers,storage pipes 520 and connecting lines 522A-522F. In examples, storagepipe 520 can be buried beneath ground 525. In examples, system 500 canbe connected to adjacent storage system 530 that can be similar tosystem 500 or other systems described herein to increase a storagecapacity of system 500.

FIG. 12 illustrates storage system 550 comprising a plurality of storagepipes 520 interconnected into clusters 554. System 550 can be connectedto one or more producers 552 that generate or produce hydrogen, such aselectrolysis units. Clusters 554 can comprise packs of pipes 520connected to a common header pipe 556 that connects to an above-groundportion of system 550, such as line 522A. In the illustrated example,each of clusters 554 includes six of pipes 520. It will be appreciatedthat with current drilling technology, it is contemplated that systems550 can include pipes 520 that can be buried up to two miles beneathground 525 level. For comparison, pipes 520 can be stacked end-to-end alength that is equivalent to nine Empire State buildings as acomparative reference. In examples of system 500 of FIG. 11 or system550 of FIG. 12, the depths utilized are expected to be directly relatedto the amounts of hydrogen needed to be stored. That is, longer pipescan be extended further underground to store higher amounts (e.g.,volumes) of hydrogen.

In examples, pipe 520 can be a steel pipe that has been inserted into awell bore. In examples, pipe 520 can be made of other material, such asfiber reinforced composite materials and other metals and alloys. Inexamples, pipe 520 can comprise a standard well casing, or plurality ofwell casings that have been joined in a manner sufficient to contain thehydrogen. In examples, other storage arrangements can be used, such asto treat the well to make it suitable to contain the hydrogen, such asto make the geology surrounding the well impermeable to hydrogen.

The vertical cylindrical tank or vessel of pipe 520 can store gas at ahigh pressure P_(high) and supply a volume of hydrogen, when needed,down to a lower pressure P_(low). As such, the storage capacity ofhydrogen in any such pipe can be the amount of hydrogen that can bestored within the volume of pipe 520 at P_(high) minus the amount ofhydrogen that can be stored within the volume of pipe 520 at P_(low).Installation techniques for placing pipes 520 below ground 525 caninclude excavation or drilling. Additionally, pipes 520 can be installedin an existing (such as an abandoned) oil and/or gas production well.The various supporting subsystems, such as valves, transducers, headers,and/or manifolds can be installed either above or below the grade ofground 525.

It will be appreciated that compressor 505 consumes energy to compressthe hydrogen up to the required storage pressures, such as P_(high). Itis expected that during times of low demand for hydrogen (and/orelectricity), which can coincide with times of peak production andavailability of renewable electricity, compressor 505 can be operated tocompress the hydrogen to the required storage pressures. Likewise,during periods of high demand for hydrogen (and/or electricity),compressor 505 can be turned off to conserve electricity, and hydrogencan be drawn from pipes 520 to provide energy, such as electricity, viathermal combustion and/or one or more fuel cells.

As the pressure of hydrogen in pipes 520 can approach (or even fallbelow) P_(low), compressor 505 can be used to draw hydrogen from pipes520 and provide it at any particular, desired pressure, which can begreater than the pressure within pipes 520.

FIG. 13A illustrates storage system 560. Storage system 560 can besimilar to storage system 500 (FIG. 1). However, storage system 560 cancomprise vessels 562 (such as pipes) that includes a directional change.Vessels 562 can comprise vertical portion 564 and horizontal portion566. It is contemplated that directional drilling techniques utilized inother industries (such as oil, gas, and/or water exploration) can beutilized to increase the storage capacity of a system 500 without theneed to dig as deep, or when an obstruction impedes or obstructsdrilling as deep as would otherwise be desired. As described above,multiple systems 560 can be arranged within clusters 568 in fluidcommunication together to provide increased storage capacity. As shownin FIG. 13B, each cluster 568 can comprise a matrix of six vessels 562from one of systems 560. Clusters 568 can be stacked vertically.

FIGS. 14A and 14B depict a top view and a side view of clusterarrangement 570. Cluster arrangement 570 comprises a radial shape thatcan allow for efficient use of the space above ground, such that all ofthe associated subsystems can be located near a common connection pointto many storage vessels. Cluster arrangement 570 can comprise vessels572 arranged where first ends of vessels 572 are located near centerportion 574 where end of vessels are close together and vessels 572 canextend radially away from center portion 574 to outer portion 576 whereends of vessels 572 are far apart. Vessels 572 can comprise pipes asdescribed herein and can be arranged in straight configurations orconfigurations having directional changes, either curved or angular.

FIG. 15 is a schematic illustration of storage system 580. System 580depicts an arrangement having three layers 582, 584, 586 of vessels 588.Layers 582-586 can connect to line 522A in a variety of manners. Vessels588 in each layer 582, 584, 586 can be individually piped above gradeusing lines 590, such as is shown by layer 582 of Layer 1 at header pipe592. Individual vessels 588 can be connected to common header 592 vialine 594 prior to piping above grade, such as is shown by thearrangement of layer 584 of Layer 2. Individual layers can beindependent, such as shown by Layer 1, or be in fluid communication withlayers above or below, such as is shown in the connection between layer584 of Layer 2 and layer 584 of Layer 3 using lines 596.

FIGS. 16A-16C show various section views of layers 582-586. FIG. 16Ashows layers 582-586 arranged in a symmetrical manner. FIGS. 16B and 16Cshow layers 582-586 arranged in an asymmetrical manner. Layers 582-586can be arranged for purposes of minimizing cost of mechanical supportsbetween individual vessels 588, as well as reducing the overall spacerequired. In examples, vessels 588 can be secured in place by earth orby artificial supports.

FIGS. 16D and 16E illustrate an alternative layering arrangement wherevessels 588 are arranged in trench 590.

Vessels 588 in any configuration can be installed fully subsurface orwith access gallery 596 at the end for maintenance and inspections, orlocation of various subsystems, as shown in FIG. 16F. Thus, valvesconnected to ends of vessels 588 can be accessible.

FIGS. 17, 17A and 17B illustrate views of gantry system 600. Gantrysystem 600 can be used for fabrication and installation of variousvessels described herein.

FIG. 17 illustrates an overhead view of gantry system 600 comprisingsupport structures 602 having vertical portions 604 and horizontalportions 606. FIG. 17A is a side view of gantry system 600 showingvertical portions 604 spaced apart. FIG. 17B is a side view of gantrysystem 600 showing vertical portions 604 connected by horizontal portion606.

Gantry system 600 can be installed above trench 608. Vertical portions604 can be installed into ground above grade 525 along opposite sides oftrench 608. Horizontal portions 606 can connect vertical portions 604 onopposite sides of trench 608. Vertical portions 604 and horizontalportions 606 can form temporary support structure 602.

FIG. 18 illustrates an overhead view of welding gantry 620 relative tosupport structure 602 of gantry system 600. FIG. 18A is a side view ofwelding gantry 620 showing vessel 622 and welding unit 621, with gantrysystem 600 omitted for clarity. FIG. 18B is a side view of gantry system600 showing welding gantry 620 disposed on wheels 624 within supportstructure 602.

Welding gantry 620 can comprise lower frame 626 to which wheels 624 canbe mounted. Lower frame 626 can be connected to upper frame 628 viasupports 630. Vessels 622 can be suspended from upper frame 628 usingcables 632 and hoists 634. Welding gantry 620 can comprise welding unit621 that can weld together discrete sections 636 to form vessel 622 thatis greater in length than discrete sections 636 individually. Weldingunit 621 can be totally enclosed to manage pre and post weld heattreatment, radiography, climate control etc. In examples, welding unit621 can also be open to atmosphere or partially sheltered in order toprovide a lower cost alternative for applications for which therequirements can be less demanding. Welding gantry 620 can berobotically controlled to move along gantry system 600 and to performwelding operations with welding unit 621.

In examples, a first step can be to excavate away earth at grade 525 toprovide a location for trench 608 for vessels 622. Following excavationof the site, temporary support structure 602 can be installed. Temporarysupport structure 602 can comprise vertical portions 604 and horizontalportions 606. After the installation of support structure 602, weldinggantry 620 with welding unit 621 can be installed, and various sections636 of pipes can be joined to obtain the desired vessel length. Weldinggantry 620 can include hoist 634 with a trolly for moving pipe sections636 into place on the work platform. Gantry 620 can include hoists 634on each side of temporary support structure 602, so that sections 636 ofpipe can be provided on either side of the structure, to optimizeconstruction efficiency, such as welding procedures.

FIG. 19 illustrates an overhead view of gantry system 600 showing thelocation of welding gantry 620 relative to trench 608. FIG. 19A is aside view of gantry system 600 showing temporary support structure 602supporting section 636 of assembled pipe forming vessel 622 and weldinggantry 620 supporting another section 636 of pipe. FIG. 18B is a sideview of gantry system 600 showing temporary support structure 602 andwelding gantry 620 holding sections 636 of pipe at the same horizontallevel.

FIGS. 20-20B illustrate further construction details and installationsteps relating to use of system 600. Temporary support structure 602 caninclude wire ropes 640 that are connected to synchronized hoists 638 inorder to evenly lower vessels 622 into trench 608. Welding gantry 620can be supported by structure 602, beneath sections 636 of pipe, and canmove from section to section to weld together the ends thereof to formvessels 622 of desired length.

FIGS. 21-22B depict further installation steps using system 600. As eachvessel 622 is welded together to the desired length, each vessel 622 canbe lowered via hoists 638 into trench 608, and arranged as desired. As alayer of vessels 622 is completed, earth 642 can be backfilled intotrench 308 onto the first layer of vessels 622 to support the followinglayer of vessels 622. If a gallery access is to be employed (see FIG.16F), earth 636 will not cover the end for the gallery. This willcontinue until, as is shown in FIG. 23A-23C, the full arrangement oflayers of vessels 622 are provided and backfilled with earth, or othersupport structure as are be appropriate. FIG. 23A shows vessels 622completely buried with just header pipe 644 extending above grade 525 ofearth 642.

Gantry system 600 including temporary support structure 602 and weldinggantry 620 can allow for in-place assembly of long lengths of assembledpipe that can be lowered into place as fabricated. Hoists 638 can moveside-to-side and lengthwise along support structure 602 to provideaccess to all of trench 608. Wire ropes 640 can move sections of pipevertically relative to trench 608. As such, sections of pipe can bemoved into various three-dimensional positions in trench 608. Weldinggantry 620 can move lengthwise within support structure 602 above trench608. Hoists 634 can move side-to-side and on gantry 620 to provideaccess to all of trench 608. Cables 632 can move sections of pipevertically relative to trench 608. As such, sections of pipe can bemoved into various three-dimensional positions in trench 608. Thus,welding gantry 620 can be used to load sections of pipe into supportstructure 602 and assemble additional sections of pipe onto sections ofpipe supported by support structure 602. Welding gantry 620 can move outof the way of support structure 602 or work with support structure 602to move assembled lengths of pipe sections into trench 608.

FIGS. 24-27 depict storage system 700 over a sequence of steps in whichpipe storage systems 702, 704, 706 and 708 are sequentially added, ascan accommodate a need for increasing hydrogen storage capacity. Storagesystem 700 can comprise storage controller 710 for communicating withmaster controller 108 for communicating with grid 128 (FIGS. 1A and 1B).

FIG. 24 depicts first system 702 that includes hydrogen production unit712 and consumer 714 that consumes hydrogen. Hydrogen production unit712 and consumer 714 can be connected by piping 716. Additionally,system 702 can include appropriate sensors 718 and actuators and be insignal and control communication with a storage controller 710, which iscapable to operate system 700 and associated subsystems (as describedabove with reference to other figures herein, particularly FIGS. 11-23C)in order to store and provide hydrogen in response to appropriateconditions, as can be defined, or directed by, grid controller 108.Compressor 722 can be provided in piping 716 to compress and movehydrogen throughout system 702. In examples, first system 702 can beconfigured similarly as system 550 of FIG. 12.

FIG. 25 depicts the addition of second storage system 704 having saltcavern 730 as a storage system, rather than the vessels described above.System 704 can have hydrogen production unit 732 and consumers 734.Additionally, system 704 can include appropriate sensors 736 andactuators, and be in in signal and control communication with thestorage controller 710, which is capable to operate system 704associated subsystems (as described above with reference to otherfigures herein, particularly FIGS. 11-23C) in order to store and providehydrogen in response to appropriate conditions, as can be defined, ordirected by, grid controller 108. Compressor 738 can be provided inpiping 740 to compress and move hydrogen throughout system 704. Asdepicted in FIG. 25, systems 702 and 704 can each be in signal andcontrol communication with controller 710, but are separated in terms ofthe ability of each to distribute hydrogen. That is, storage of system702 cannot receive hydrogen from producer 732 of system 704 and cannotprovide hydrogen to consumer 734 of system 704. Likewise, the hydrogenstored within system 704 cannot be exchanged with the producer 712 orconsumer 714 of system 702.

FIG. 26 depicts the addition of third storage system 706. As will beappreciated, storage system 706 includes the same components as system702 and described with reference to FIG. 24, which will not be describedhere for the sake of brevity. As depicted in FIG. 26, all systems 702,704 and 706 can each be in signal and control communication with storagecontroller 710. Systems 702 and 706 are connected in terms of theirability to distribute hydrogen. That is, storage of system 700 canreceive hydrogen from producer 712 of system 706 and can providehydrogen to consumer 714 of system 706. Likewise, the hydrogen storedwithin system 706 can be exchanged with producer 712 or consumer 714 ofsystem 700. However, as depicted in FIG. 26, systems 700 and 706 areseparated from system 704 in terms of the ability of each to distributehydrogen to system 704.

FIG. 27 depicts the addition of fourth storage system 708. As will beappreciated, storage system 708 includes the same components as system702 and described with reference to FIG. 24, which will not be labeledor described here for the sake of brevity. As depicted in FIG. 27,systems 702, 704, 706 and 708 can each be in signal and controlcommunication with the storage controller 710. FIG. 27 depicts that theintroduction of system 708 “bridges together” systems 702 and 706 withsystem 704. Systems 702, 704, 706, and 708 are thereby all connected interms of the ability of each to distribute hydrogen amongst each other.That is, the storage of each of the systems 702, 702, 704 and 708 canreceive hydrogen from producers 712 and producer 732 of any of the othersystems 702, 704, 706 and 708 and can provide hydrogen to consumers 714and producer 734 of any of the other systems 702, 704, 706 and 708. Insuch a situation, the vast storage quantities of hydrogen related to thesalt cavern 704 can be utilized by the other systems. Additionally, ifany hydrogen producer from any of the systems 702, 704, 706, or 708becomes inoperative, or is unavailable as a result of maintenance orrepair, the hydrogen produced or stored by any of the other systems canbe available for use by the consumer associated with the system that isotherwise unavailable.

Storage system 700 can comprise an example of hydrogen storage system110 of FIGS. 1A and 1B. In additional examples, hydrogen storage system110 of FIGS. 1A and 1B can comprise one of systems 702, 704, 706 and708.

FIG. 29 is a schematic diagram illustrating components of controller 108for operating integrated power production system 100 and controllers120-126 for operating hydrogen production system 106 and GTCC 104.Controller 108 can include circuit 80, power supply 82, memory 84,processor 86, input device 88, output device 90 and communicationinterface 92. Controller 108 can be in communication with grid 128,which can provide power to end users or consumers 152. Controller 108can also be in communication with controllers 120 and 122 for hydrogenproduction system 106 and controllers 124 and 126 for GTCC 104, whichcan be in communication with one or more sub-system controllers, such asstorage controller 24A and battery and generator controller 24B.Controller 24A can be in communication with hydrogen storage system 110and oxygen storage system 112, as well as various components thereof,such as valves 142-144, compressor 138, turbine 226 and compressor 254,and purification units 136 and 140. Controller 24B can be incommunication with batteries 222 and 430, as well as various othercomponents, such as breakers 410A-410F and clutches 160 and 214.

Controllers 120-126 and controllers 24A and 24B can also include variouscomputer system components that facilitate receiving and issuingelectronic instructions, storing instructions, data and information,communicating with other devices, display devices, input devices, outputdevices and the like. For example, power controllers 120-126 can eachinclude power supply 50, memory 52, processor 54, control circuit 56 andthe like.

Circuit 80 can comprise any suitable computer architecture such asmicroprocessors, chips and the like that allow memory 84, processor 86,input device 88, output device 90 and communication interface 92 tooperate together. Power supply 82 and power supply 100 can comprise anysuitable method for providing electrical power to controller 108 andcontrollers 120-126, respectively, such as AC or DC power supplies.Memory 84 and memory 52 can comprise any suitable memory devices, suchas random access memory, read only memory, flash memory, magnetic memoryand optical memory. Input device 88 can comprise a keyboard, mouse,pointer, touchscreen and other suitable devices for providing a userinput or other input to circuit 80 or memory 84. Output device 90 cancomprise a display monitor, a viewing screen, a touch screen, a printer,a projector, an audio speaker and the like. Communication interface 92can comprise devices for allowing circuit 80 and controller 108 toreceive information from and transmit information to other computingdevices, such as a modem, a router, an I/O interface, a bus, a localarea network, a wide area network, the internet and the like.

Controller 108 can be configured to operate grid 128 and, as such, canbe referred to the “home office” for system 100. Grid 128 can comprisehydrogen production system 106, GTCC 104, renewable energy sources 130and 132, high voltage transmission lines that carry power from distantsources to demand centers, and distribution lines that connect consumers152. Grid 128 can be configured to operate at a control frequency whereall power input into the grid from disparate sources in input at thesame frequency to facilitate integration of the power. In an example,grid 128 can operate at a control frequency of 60 Hertz (Hz).

Controller 108 can determine the demand being placed on grid 128, suchas by monitoring the consumption of consumers 152. Controller 108 cancoordinate generation of power from GTCC 104 and renewable energysources 130 and 132. Controller 108 can assign or instruct GTCC 104 howmuch power output they should contribute to grid 128, and suchassignment may be dynamic and reactive based upon the capabilities andavailability of any of GTCC 104 and renewable energy sources 130 and132. Controller 108 can ensure that the total power generated by GTCC104 and renewable energy sources 130 and 132 meets the power demand ofconsumers 152. If power demand of consumers 152 exceeds or is less thanpower supplied by GTCC 104 and renewable energy sources 130 and 132,controller 108 can dictate response strategies for GTCC 104. Thus,controller 108 can interface with controller 124 and 126 for GTCC 104.

Circuit 80 can communicate with, that is, read from and write to, amemory device such as memory 84. Memory 84 can include various computerreadable instructions for implementing operation of grid 128. Thus,memory 84 can include instructions for monitoring demand on and powerbeing supplied to grid 128. Circuit 80 can be connected to varioussensors to perform such functions. Memory 84 can also includeinformation that can assist controller 108 in providing instruction tocontrollers 120-126. For example, memory 84 can include the type, size(capacity), age, maintenance history, location, the location within thegeography covered by grid 128, and proximity to consumers 152 of each ofGTCC 104. Memory 84 can also include instructions for determining thepercentage of GTCC 104, as well as other power plants, contribution tothe total power supply.

Controllers 120-126 can be configured to operate GTCC 104 and hydrogenproduction system 106. Memory 52 can include various computer readableinstructions for implementing operation of GTCC 104 and hydrogenproduction system 106. Thus, memory 102 can include instructions formonitoring a power generation assignment from controller 108,instructions for power generation for each generators 156 and 158, andthe like. Memory 102 can additionally include instructions for operatingelectrolyzers 201 and electrolysis units 428.

Additionally, memory 52 can include operational efficiency information,such as productive and economical efficiency information for each ofgenerator units 156 and 158, including gas turbine 114. For example,memory 52 can include the electrical production efficiency of each ofturbine 114. Memory 52 can include economical information such asmaintenance and economical history for gas turbine 114, as well as timesince last service, repair, overhaul, refurbishment status, etc. Memory52 can also include information relating to operational efficiency ofGTCC 104 including the financial efficiency of each of gas turbine 114,such as various contractual obligations for operators of various powerplants and manufacturers of and service providers for gas turbine 114.

Controllers 120-126 can operate or be in communication with controllers24A and 24B to operate compressor 138, turbine 226, compressor 254,valves 142-144, purification units 136 and 140, breakers 410A-410F andclutches 160 and 214, as well as other components of system 100.

Controller 108 can work in conjunction with controllers 120-126 tooperate controllers 24A and 24B to maximize or most efficiently operatesystem 100, such as by controlling operation of hydrogen productionsystems 106 to produce hydrogen when conditions on grid 128 permit.Thus, memory 52 and memory 84 can include instructions for operating orperforming any of the methods described herein, such as those describedwith reference to TABLE 1 and Cases 1-6 and the seven operating statesdescribed with reference to FIG. 10.

Various Notes & Examples

Integrated Power Generation System

Example 1 is a power plant configured to output power to a grid powersystem, comprising: a hydrogen generation system configured to producehydrogen; a gas turbine combined cycle power plant comprising: a gasturbine engine configured to combust hydrogen from the hydrogengeneration system to generate a gas stream that can be used to rotate aturbine shaft; and a heat recovery steam generator (HRSG) configured togenerate steam with the gas stream of the gas turbine engine to rotate asteam turbine; a storage system configured to store hydrogen produced bythe hydrogen generation system; and a controller configured to: operatethe hydrogen generation system with electricity from the grid powersystem when the grid power system has excess energy; and balance activeand reactive loads on the grid power system using at least one of thehydrogen generation system and the gas turbine combined cycle powerplant.

In Example 2, the subject matter of Example 1 optionally includes apower conversion device connecting the hydrogen generation system to thegrid power system, the power conversion device comprising: a DCconverter to convert DC power from the hydrogen generation system toclean AC power for the grid power system; and an AC converter to convertAC power from the grid power system to DC power for the hydrogengeneration system.

In Example 3, the subject matter of any one or more of Examples 1-2optionally include wherein: the DC converter comprises a chopperconverter or thyristor converter; and the AC converter comprises a powerconversion system.

In Example 4, the subject matter of any one or more of Examples 1-3optionally include wherein: the gas turbine engine is connected to a gasturbine electric generator via a first clutch; and the controller isconfigured to selectively activate the first clutch to permit the gasturbine electric generator to spin freely to absorb reactive loads.

In Example 5, the subject matter of any one or more of Examples 1-4optionally include wherein: the steam turbine is connected to a steamturbine electric generator via a second clutch; and the controller isconfigured to selectively activate the second clutch to permit the steamturbine electric generator to spin freely to absorb reactive loads.

In Example 6, the subject matter of any one or more of Examples 1-5optionally include a battery connected to the grid power system toprovide load and frequency support.

In Example 7, the subject matter of Example 6 optionally includes arenewable energy producer connected to the grid system, wherein thebattery can be charged from the renewable energy producer without thegrid power system.

In Example 8, the subject matter of any one or more of Examples 1-7optionally include an auxiliary burner configured to burn hydrogen fromthe hydrogen production system to heat the hydrogen production system.

In Example 9, the subject matter of any one or more of Examples 1-8optionally include wherein the hydrogen production system comprises anelectrolyzer.

In Example 10, the subject matter of Example 9 optionally includes aheating source for heating the electrolyzer, the heating sourcecomprising a resistance heater or a power conversion device.

In Example 11, the subject matter of any one or more of Examples 9-10optionally include a heat exchange circuit connected to the electrolyzerto cool or heat the electrolyzer.

In Example 12, the subject matter of Example 11 optionally includeswherein the heat exchange circuit is connected to the gas turbinecombined cycle power plant and is provided with steam.

In Example 13, the subject matter of any one or more of Examples 11-12optionally include wherein: the electrolyzer is further configured toproduce oxygen; and the power plant further comprises an oxygen storagesystem.

In Example 14, the subject matter of Example 13 optionally includeswherein the heat exchange circuit is provided with cooled oxygen fromthe electrolyzer.

In Example 15, the subject matter of any one or more of Examples 13-14optionally include an oxygen turbine driven by oxygen from theelectrolzyer; and an electrical generator driven by the oxygen turbine.

In Example 16, the subject matter of any one or more of Examples 9-15optionally include a conduit connecting oxygen output of theelectrolyzer to a HRSG of the gas turbine combined cycle power plant.

In Example 17, the subject matter of Example 16 optionally includes m/sor greater.

In Example 18, the subject matter of any one or more of Examples 1-17optionally include burning the hydrogen in the HRSG using a supplementalfiring burner.

In Example 19, the subject matter of any one or more of Examples 1-18optionally include a natural gas source connected to the gas turbineengine and the gas turbine engine is configured to combust natural gas,hydrogen and combinations thereof.

In Example 20, the subject matter of any one or more of Examples 1-19optionally include wherein the hydrogen storage system comprises anunderground storage system.

In Example 21, the subject matter of Example 20 optionally includeswherein the hydrogen storage system comprises a salt cavern.

In Example 22, the subject matter of any one or more of Examples 20-21optionally include wherein the hydrogen storage system comprises aplurality of pipes.

In Example 23, the subject matter of Example 22 optionally includestemporary support structure comprising hoists configured to place pipesin a trench; and a welding gantry operable with the temporary supportstructure to assemble sections of pipe.

Injector

Example 1 is a power plant configured to output power to a grid powersystem, comprising: an electrolyzer configured to produce hydrogen andoxygen; a gas turbine combined cycle power plant comprising: a gasturbine engine configured to combust hydrogen from the hydrogengeneration system to generate a gas stream that can be used to rotate aturbine shaft; and a heat recovery steam generator (HRSG) configured togenerate steam with the gas stream of the gas turbine engine to rotate asteam turbine; a storage system configured to store hydrogen produced bythe hydrogen generation system; and a nozzle configured to introduceoxygen from the electrolyzer into the HRSG of the gas turbine combinedcycle power plant.

In Example 2, the subject matter of Example 1 optionally includeswherein the nozzle comprises: an injector configured to receive fuel;and a housing into which the injector extends and into which the oxygenenters, the housing comprising a plurality of mixing ports arrangedradially of the injector to allow mixed fuel and oxygen out of thenozzle.

In Example 3, the subject matter of Example 2 optionally includeswherein the plurality of radial mixing ports are configured to generatemixing vortices to reduce the production of NOX in the gas stream.

Example 4 is a method of combusting fuel using a thermal nozzle, themethod comprising: (A) providing oxidant having an oxygen concentrationof at least 30 volume percent at an initial velocity less than 300 fpswithin an oxidant supply duct communicating with a combustion zone; (B)providing fuel separately from oxidant into the oxidant supply duct at ahigh velocity of greater than 200 feet per second and greater than saidoxidant initial velocity entraining oxidant into the high velocity fuel,combusting up to about 20 percent of the oxygen of the oxidant providedinto the oxidant supply duct with the fuel to produce heat andcombustion reaction products in a combustion reaction, and furtherentraining combustion reaction products and oxidant into the combustionreaction; (C) mixing combustion reaction products with remaining oxygenof the oxidant within the oxidant supply duct and raising thetemperature of remaining oxidant within the oxidant supply duct; and (D)passing heated oxidant out from the oxidant supply duct into thecombustion zone at an exit velocity which exceeds the initial velocityby at least 300 feet per second; wherein the heated oxidant passes outof the oxidant supply duct from a plurality of orifices arranged indifferent orientations.

Hybrid Power Converter

In Example 1, the subject matter of Example undefined optionallyincludes, wherein the power converter is configured to convert: AC powerfrom the grid power system to DC power for the electrolyzer; and DCpower from the electrolyzer to AC power for the grid power system.

In Example 2, the subject matter of Example undefined optionallyincludes, wherein the power converter comprises: a DC convertercomprising a chopper converter or thyristor converter; and a ACconverter comprising a power conversion system.

In Example 3, the subject matter of Example undefined optionallyincludes, further comprising a battery configured to absorb active andreactive loads on the grid power system.

In Example 4, the subject matter of Example 3 optionally includes arenewable energy producer configured to supply power to the batterywithout the grid power system.

Operating State Methods

Example 1 is a method of operating an integrated power plant connectedto a grid power system, the method comprising: operating a gas turbineengine to drive a first electric generator to provide power to the gridpower system, the gas turbine engine operable on at least one ofhydrogen and natural gas; operating an electrolyzer to generate hydrogenand oxygen with electricity from the grid power system; storing hydrogenproduced by the electrolyzer in a storage system; and coordinatingoperation of the gas turbine engine and electrolyzer to power demand ofthe grid power system.

In Example 2, the subject matter of Example 1 optionally includeswherein coordinating operation of the gas turbine engine andelectrolyzer to power demand of the grid power system comprises:starting the gas turbine engine from shut down to operate at maximumoutput; and shutting down operation of the electrolyzer; wherein thedemand of the grid power system is a call for maximum power.

In Example 3, the subject matter of Example 2 optionally includeswherein: the gas turbine engine is starting from 0% load; and theelectrolyzer is starting from 100% load operating from renewable energyconnected to the grid power system.

In Example 4, the subject matter of any one or more of Examples 1-3optionally include wherein coordinating operation of the gas turbineengine and electrolyzer to power demand of the grid power systemcomprises: ramping up operation of the gas turbine engine from a partialload status at a maximum ramp rate; and shutting down operation of theelectrolyzer; wherein the demand of the grid power system is a call formaximum power.

In Example 5, the subject matter of Example 4 optionally includeswherein: the gas turbine engine is starting from 30% load and isoperating with natural gas; and the electrolyzer is starting from 100%load.

In Example 6, the subject matter of any one or more of Examples 1-5optionally include wherein coordinating operation of the gas turbineengine and electrolyzer to power demand of the grid power systemcomprises: ramping down operation of the gas turbine engine from amaximum load status; and starting operation of the electrolyzer; whereinthe demand of the grid power system changes from maximum power to areduced power demand.

In Example 7, the subject matter of Example 6 optionally includeswherein: the gas turbine engine is starting from 100% load and isoperating with natural gas and hydrogen from the electrolyzer; and theelectrolyzer is starting from 0% load.

In Example 8, the subject matter of any one or more of Examples 1-7optionally include wherein coordinating operation of the gas turbineengine and electrolyzer to power demand of the grid power systemcomprises: operating the gas turbine engine in a standby mode; andshutting down operation of the electrolyzer; wherein the demand of thegrid power system is constant.

In Example 9, the subject matter of Example 8 optionally includeswherein: the gas turbine engine is starting from being shut down; theelectrolyzer is one of a plurality of electrolyzers, wherein 50% of theplurality of electrolyzers are starting from 0% load and 50% of theelectrolyzers are starting from 100% load; and wherein power beingsupplied to the grid power supply by renewable energy output drops.

In Example 10, the subject matter of any one or more of Examples 1-9optionally include wherein coordinating operation of the gas turbineengine and electrolyzer to power demand of the grid power systemcomprises: ramping up operation of the gas turbine engine to full speed;and reducing output of the electrolyzer; wherein the demand of the gridpower system is increased.

In Example 11, the subject matter of Example 10 optionally includeswherein: the gas turbine engine is brought up to speed with no load andis operating with natural gas and hydrogen from the electrolyzer; andthe electrolyzer is starting from 100% load operating from renewableenergy connected to the grid power system.

In Example 12, the subject matter of any one or more of Examples 1-11optionally include wherein coordinating operation of the gas turbineengine and electrolyzer to power demand of the grid power systemcomprises: ramping up operation of the gas turbine engine from anon-operating state; and shutting down operation of the electrolyzer;wherein the demand of the grid power system is increasing.

In Example 13, the subject matter of Example 12 optionally includeswherein: the gas turbine engine is starting from performing gridcondensing operations and initiates operation with natural gas first andthen hydrogen; and the electrolyzer is starting from 100% load.

In Example 14, the subject matter of any one or more of Examples 1-13optionally include operating a heat recovery steam generator (HRSG) towith exhaust gas of the gas turbine engine to rotate a steam turbine todrive a second electric generator.

In Example 15, the subject matter of any one or more of Examples 1-14optionally include heating the electrolyzer with steam from the HRSG.

The above detailed description includes references to the accompanyingdrawings, which form a part of the detailed description. The drawingsshow, by way of illustration, specific embodiments in which theinvention can be practiced. These embodiments are also referred toherein as “examples.” Such examples can include elements in addition tothose shown or described. However, the present inventor alsocontemplates examples in which only those elements shown or describedare provided. Moreover, the present inventor also contemplates examplesusing any combination or permutation of those elements shown ordescribed (or one or more aspects thereof), either with respect to aparticular example (or one or more aspects thereof), or with respect toother examples (or one or more aspects thereof) shown or describedherein.

In the event of inconsistent usages between this document and anydocuments so incorporated by reference, the usage in this documentcontrols.

In this document, the terms “a” or “an” are used, as is common in patentdocuments, to include one or more than one, independent of any otherinstances or usages of “at least one” or “one or more.” In thisdocument, the term “or” is used to refer to a nonexclusive or, such that“A or B” includes “A but not B,” “B but not A,” and “A and B,” unlessotherwise indicated. In this document, the terms “including” and “inwhich” are used as the plain-English equivalents of the respective terms“comprising” and “wherein.” Also, in the following claims, the terms“including” and “comprising” are open-ended, that is, a system, device,article, composition, formulation, or process that includes elements inaddition to those listed after such a term in a claim are still deemedto fall within the scope of that claim. Moreover, in the followingclaims, the terms “first,” “second,” and “third,” etc. are used merelyas labels, and are not intended to impose numerical requirements ontheir objects.

The above description is intended to be illustrative, and notrestrictive. For example, the above-described examples (or one or moreaspects thereof) may be used in combination with each other. Otherembodiments can be used, such as by one of ordinary skill in the artupon reviewing the above description. The Abstract is provided to complywith 37 C.F.R. § 1.72(b), to allow the reader to quickly ascertain thenature of the technical disclosure. It is submitted with theunderstanding that it will not be used to interpret or limit the scopeor meaning of the claims. Also, in the above Detailed Description,various features may be grouped together to streamline the disclosure.This should not be interpreted as intending that an unclaimed disclosedfeature is essential to any claim. Rather, inventive subject matter maylie in less than all features of a particular disclosed embodiment.Thus, the following claims are hereby incorporated into the DetailedDescription as examples or embodiments, with each claim standing on itsown as a separate embodiment, and it is contemplated that suchembodiments can be combined with each other in various combinations orpermutations. The scope of the invention should be determined withreference to the appended claims, along with the full scope ofequivalents to which such claims are entitled.

The claimed invention is:
 1. A power plant configured to output power toa grid power system, comprising: a hydrogen generation system configuredto produce hydrogen; a gas turbine combined cycle power plantcomprising: a gas turbine engine configured to combust hydrogen from thehydrogen generation system to generate a gas stream that can be used torotate a turbine shaft; and a heat recovery steam generator (HRSG)configured to generate steam with the gas stream of the gas turbineengine to rotate a steam turbine; a storage system configured to storehydrogen produced by the hydrogen generation system; and a controllerconfigured to: operate the hydrogen generation system with electricityfrom the grid power system when the grid power system has excess energy;and balance active and reactive loads on the grid power system using atleast one of the hydrogen generation system and the gas turbine combinedcycle power plant.
 2. The power plant of claim 1, further comprising apower conversion device connecting the hydrogen generation system to thegrid power system, the power conversion device comprising: a DCconverter to convert DC power from the hydrogen generation system toclean AC power for the grid power system; and an AC converter to convertAC power from the grid power system to DC power for the hydrogengeneration system.
 3. The power plant of claim 1, wherein: the DCconverter comprises a chopper converter or thyristor converter; and theAC converter comprises a power conversion system.
 4. The power plant ofclaim 1, wherein: the gas turbine engine is connected to a gas turbineelectric generator via a first clutch; and the controller is configuredto selectively activate the first clutch to permit the gas turbineelectric generator to spin freely to absorb reactive loads.
 5. The powerplant of claim 1, wherein: the steam turbine is connected to a steamturbine electric generator via a second clutch; and the controller isconfigured to selectively activate the second clutch to permit the steamturbine electric generator to spin freely to absorb reactive loads. 6.The power plant of claim 1, further comprising a battery connected tothe grid power system to provide load and frequency support.
 7. Thepower plant of claim 6, further comprising a renewable energy producerconnected to the grid system, wherein the battery can be charged fromthe renewable energy producer without the grid power system.
 8. Thepower plant of claim 1, further comprising an auxiliary burnerconfigured to burn hydrogen from the hydrogen production system to heatthe hydrogen production system.
 9. The power plant of claim 1, whereinthe hydrogen production system comprises an electrolyzer.
 10. The powerplant of claim 9, further a heating source for heating the electrolyzer,the heating source comprising a resistance heater or a power conversiondevice.
 11. The power plant of claim 9, further comprising a heatexchange circuit connected to the electrolyzer to cool or heat theelectrolyzer.
 12. The power plant of claim 11, wherein the heat exchangecircuit is connected to the gas turbine combined cycle power plant andis provided with steam.
 13. The power plant of claim 11, wherein: theelectrolyzer is further configured to produce oxygen; and the powerplant further comprises an oxygen storage system.
 14. The power plant ofclaim 13, wherein the heat exchange circuit is provided with cooledoxygen from the electrolyzer.
 15. The power plant of claim 13, furthercomprising: an oxygen turbine driven by oxygen from the electrolzyer;and an electrical generator driven by the oxygen turbine.
 16. The powerplant of claim 9, further comprising: a conduit connecting oxygen outputof the electrolyzer to a HRSG of the gas turbine combined cycle powerplant; and a nozzle connected to an inlet of the HRSG to inject theoxygen from the electrolyzer at a high velocity of 750 m/s or greater.17. The power plant of claim 1, further comprising burning the hydrogenin the HRSG using a supplemental firing burner.
 18. The power plant ofclaim 1, further comprising a natural gas source connected to the gasturbine engine and the gas turbine engine is configured to combustnatural gas, hydrogen and combinations thereof.
 19. The power plant ofclaim 1, wherein the hydrogen storage system comprises an undergroundstorage system comprising at least one of a salt cavern and a pluralityof pipes.
 20. The power plant of claim 19, further comprising: temporarysupport structure comprising hoists configured to place pipes in atrench; and a welding gantry operable with the temporary supportstructure to assemble sections of pipe.